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Table of Contents
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)

☒ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |

For the quarterly period ended | March 31, 2025 |

|  | or |  |

☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |

For the transition period from |  | to |  |

Commission file number: | 001-35349 |

Phillips 66
(Exact name of registrant as specified in its charter)

Delaware |  | 45-3779385
(State or other jurisdiction of incorporation or organization) |  | (I.R.S. Employer Identification No.)

2331 CityWest Blvd., Houston, Texas 77042
(Address of principal executive offices) (Zip Code)
832-765-3010
(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:
| Title of each class |  | Trading Symbol(s) |  | Name of each exchange on which registered |
| Common Stock, $0.01 Par Value |  | PSX |  | New York Stock Exchange |

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer | ☒ | Accelerated filer | ☐ | Non-accelerated filer | ☐
Smaller reporting company | ☐ | Emerging growth company | ☐ |  |

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒
The registrant had 407,581,886 shares of common stock, $0.01 par value, outstanding as of March 31, 2025.

Table of Contents
PHILLIPS 66
TABLE OF CONTENTS

| Page
Part I – Financial Information |
Item 1. Financial Statements |
Consolidated Statement of Income | 1
Consolidated Statement of Comprehensive Income | 2
Consolidated Balance Sheet | 3
Consolidated Statement of Cash Flows | 4
Consolidated Statement of Changes in Equity | 5
Notes to Consolidated Financial Statements | 6
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations | 36
Item 3. Quantitative and Qualitative Disclosures About Market Risk | 68
Item 4. Controls and Procedures | 68
Part II – Other Information |
Item 1. Legal Proceedings | 69
Item 1A. Risk Factors | 70
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds | 70
Item 5. Other Information | 70
Item 6. Exhibits | 71
Signatures | 72

Table of Contents
PART I. FINANCIAL INFORMATION
Item 1. FINANCIAL STATEMENTS

Consolidated Statement of Income | Phillips 66

| Millions of Dollars |
| Three Months Ended March 31 |  |
| 2025 |  |  | 2024 |  |  |  |  |
Revenues and Other Income |  |  |  |  |  |  |
Sales and other operating revenues | $ | 30,430 |  |  | 35,811 |  |  |  |  |
Equity in earnings of affiliates | 153 |  |  | 528 |  |  |  |  |
Net gain on dispositions | 1,087 |  |  | — |  |  |  |  |
Other income | 56 |  |  | 97 |  |  |  |  |
Total Revenues and Other Income | 31,726 |  |  | 36,436 |  |  |  |  |
Costs and Expenses |  |  |  |  |  |  |
Purchased crude oil and products | 27,660 |  |  | 32,386 |  |  |  |  |
Operating expenses | 1,622 |  |  | 1,452 |  |  |  |  |
Selling, general and administrative expenses | 519 |  |  | 557 |  |  |  |  |
Depreciation and amortization | 791 |  |  | 504 |  |  |  |  |
Impairments | 26 |  |  | 165 |  |  |  |  |
Taxes other than income taxes | 233 |  |  | 165 |  |  |  |  |
Accretion on discounted liabilities | 12 |  |  | 9 |  |  |  |  |
Interest and debt expense | 221 |  |  | 227 |  |  |  |  |
Foreign currency transaction (gains) losses | (6) |  |  | 7 |  |  |  |  |
Total Costs and Expenses | 31,078 |  |  | 35,472 |  |  |  |  |
Income before income taxes | 648 |  |  | 964 |  |  |  |  |
Income tax expense | 122 |  |  | 203 |  |  |  |  |
Net Income | 526 |  |  | 761 |  |  |  |  |
Less: net income attributable to noncontrolling interests | 39 |  |  | 13 |  |  |  |  |
Net Income Attributable to Phillips 66 | $ | 487 |  |  | 748 |  |  |  |  |
Net Income Attributable to Phillips 66 Per Share of Common Stock (dollars) |  |  |  |  |  |  |
Basic | $ | 1.19 |  |  | 1.74 |  |  |  |  |
Diluted | 1.18 |  |  | 1.73 |  |  |  |  |
Weighted-Average Common Shares Outstanding (thousands) |  |  |  |  |  |  |
Basic | 409,182 |  |  | 428,959 |  |  |  |  |
Diluted | 410,505 |  |  | 431,906 |  |  |  |  |
See Notes to Consolidated Financial Statements. |  |  |  |  |  |  |

1

Table of Contents

Consolidated Statement of Comprehensive Income | Phillips 66

| Millions of Dollars
| Three Months Ended March 31 |  |
| 2025 |  |  | 2024 |  |  |  |
Net Income | $ | 526 |  |  | 761 |  |  |  |
Other comprehensive income (loss) |  |  |  |  |  |
Defined benefit plans |  |  |  |  |  |
Amortization of net actuarial loss and settlements | 5 |  |  | 2 |  |  |  |
Plans sponsored by equity affiliates | 2 |  |  | 1 |  |  |  |
Income taxes on defined benefit plans | (1) |  |  | (1) |  |  |  |
Defined benefit plans, net of income taxes | 6 |  |  | 2 |  |  |  |
Foreign currency translation adjustments | 90 |  |  | (34) |  |  |  |
Income taxes on foreign currency translation adjustments | (2) |  |  | 2 |  |  |  |
Foreign currency translation adjustments, net of income taxes | 88 |  |  | (32) |  |  |  |
Other Comprehensive Income (Loss), Net of Income Taxes | 94 |  |  | (30) |  |  |  |
Comprehensive Income | 620 |  |  | 731 |  |  |  |
Less: comprehensive income attributable to noncontrolling interests | 39 |  |  | 13 |  |  |  |
Comprehensive Income Attributable to Phillips 66 | $ | 581 |  |  | 718 |  |  |  |

See Notes to Consolidated Financial Statements.
2

Table of Contents

Consolidated Balance Sheet | Phillips 66

| Millions of Dollars
| March 31 2025 |  | December 31 2024
Assets |  |  |
Cash and cash equivalents | $ | 1,489 |  |  | 1,738 |
Accounts and notes receivable (net of allowances of $70 million in 2025 and 2024) | 8,616 |  |  | 9,544 |
Accounts and notes receivable—related parties | 1,605 |  |  | 1,489 |
Inventories | 5,240 |  |  | 3,995 |
Prepaid expenses and other current assets | 1,329 |  |  | 1,144 |
Total Current Assets | 18,279 |  |  | 17,910 |
Investments and long-term receivables | 13,359 |  |  | 14,378 |
Net properties, plants and equipment | 34,966 |  |  | 35,264 |
Goodwill | 1,575 |  |  | 1,575 |
Intangibles | 1,167 |  |  | 1,161 |
Other assets | 2,492 |  |  | 2,294 |
Total Assets | $ | 71,838 |  |  | 72,582 |
Liabilities |  |  |
Accounts payable | $ | 10,034 |  |  | 9,792 |
Accounts payable—related parties | 691 |  |  | 512 |
Short-term debt | 1,061 |  |  | 1,831 |
Accrued income and other taxes | 1,247 |  |  | 1,060 |
Employee benefit obligations | 372 |  |  | 732 |
Other accruals | 1,478 |  |  | 1,160 |
Total Current Liabilities | 14,883 |  |  | 15,087 |
Long-term debt | 17,742 |  |  | 18,231 |
Asset retirement obligations and accrued environmental costs | 1,151 |  |  | 1,129 |
Deferred income taxes | 6,972 |  |  | 7,101 |
Employee benefit obligations | 690 |  |  | 703 |
Other liabilities and deferred credits | 2,047 |  |  | 1,868 |
Total Liabilities | 43,485 |  |  | 44,119 |
Equity |  |  |
Common stock (2,500,000,000 shares authorized at $0.01 par value) Issued (2025—658,173,402 shares; 2024—656,987,861 shares) |  |  |
Par value | 7 |  |  | 7 |
Capital in excess of par | 19,789 |  |  | 19,788 |
Treasury stock (at cost: 2025—250,591,516 shares; 2024—248,594,923 shares) | (22,995) |  |  | (22,751) |
Retained earnings | 30,785 |  |  | 30,771 |
Accumulated other comprehensive loss | (313) |  |  | (407) |
Total Stockholders’ Equity | 27,273 |  |  | 27,408 |
Noncontrolling interests | 1,080 |  |  | 1,055 |
Total Equity | 28,353 |  |  | 28,463 |
Total Liabilities and Equity | $ | 71,838 |  |  | 72,582 |

See Notes to Consolidated Financial Statements.
3

Table of Contents

Consolidated Statement of Cash Flows | Phillips 66

| Millions of Dollars
| Three Months Ended March 31
| 2025 |  |  | 2024 |
Cash Flows From Operating Activities |  |  |
Net income | $ | 526 |  |  | 761 |
Adjustments to reconcile net income to net cash provided by operating activities |  |  |
Depreciation and amortization | 791 |  |  | 504 |
Impairments | 26 |  |  | 165 |
Accretion on discounted liabilities | 12 |  |  | 9 |
Deferred income taxes | (133) |  |  | (55) |
Undistributed equity earnings | 120 |  |  | (180) |
Loss on early redemption of debt | — |  |  | 2 |
Net gain on dispositions | (1,087) |  |  | — |
Unrealized investment (gain) loss | 10 |  |  | (6) |
Other | (6) |  |  | 11 |
Working capital adjustments |  |  |
Accounts and notes receivable | 901 |  |  | 199 |
Inventories | (1,214) |  |  | (2,555) |
Prepaid expenses and other current assets | (254) |  |  | (179) |
Accounts payable | 384 |  |  | 1,678 |
Taxes and other accruals | 111 |  |  | (590) |
Net Cash Provided by (Used in) Operating Activities | 187 |  |  | (236) |
Cash Flows From Investing Activities |  |  |
Capital expenditures and investments | (423) |  |  | (628) |
Return of investments in equity affiliates | 25 |  |  | 41 |
Proceeds from asset dispositions | 2,034 |  |  | 2 |
Advances/loans—related parties | (20) |  |  | — |
Other | (25) |  |  | (80) |
Net Cash Provided by (Used in) Investing Activities | 1,591 |  |  | (665) |
Cash Flows From Financing Activities |  |  |
Issuance of debt | — |  |  | 3,815 |
Repayment of debt | (1,287) |  |  | (3,013) |
Issuance of common stock | 23 |  |  | 50 |
Repurchase of common stock | (247) |  |  | (1,164) |
Dividends paid on common stock | (469) |  |  | (448) |
Distributions to noncontrolling interests | (14) |  |  | (13) |
Other | (55) |  |  | (73) |
Net Cash Used in Financing Activities | (2,049) |  |  | (846) |
Effect of Exchange Rate Changes on Cash and Cash Equivalents | 22 |  |  | (6) |
Net Change in Cash and Cash Equivalents | (249) |  |  | (1,753) |
Cash and cash equivalents at beginning of period | 1,738 |  |  | 3,323 |
Cash and Cash Equivalents at End of Period | $ | 1,489 |  |  | 1,570 |

See Notes to Consolidated Financial Statements.
4

Table of Contents

Consolidated Statement of Changes in Equity | Phillips 66

| Millions of Dollars
| Three Months Ended March 31
| Attributable to Phillips 66 |  |
| Common Stock |  |  |  |
| Par Value | Capital in Excess of Par | Treasury Stock | Retained Earnings | Accum. Other Comprehensive Loss | Noncontrolling Interests | Total
December 31, 2024 | $ | 7 |  | 19,788 |  | (22,751) |  | 30,771 |  | (407) |  | 1,055 |  | 28,463 |
Net income | — |  | — |  | — |  | 487 |  | — |  | 39 |  | 526 |
Other comprehensive income | — |  | — |  | — |  | — |  | 94 |  | — |  | 94 |
Dividends paid on common stock ($1.15 per share) | — |  | — |  | — |  | (469) |  | — |  | — |  | (469) |
Repurchase of common stock | — |  | — |  | (244) |  | — |  | — |  | — |  | (244) |
Distributions to noncontrolling interests | — |  | — |  | — |  | — |  | — |  | (14) |  | (14) |
Benefit plan activity | — |  | 1 |  | — |  | (4) |  | — |  | — |  | (3) |
March 31, 2025 | $ | 7 |  | 19,789 |  | (22,995) |  | 30,785 |  | (313) |  | 1,080 |  | 28,353 |
December 31, 2023 | $ | 7 |  | 19,650 |  | (19,342) |  | 30,550 |  | (282) |  | 1,067 |  | 31,650 |
Net income | — |  | — |  | — |  | 748 |  | — |  | 13 |  | 761 |
Other comprehensive loss | — |  | — |  | — |  | — |  | (30) |  | — |  | (30) |
Dividends paid on common stock ($1.05 per share) | — |  | — |  | — |  | (448) |  | — |  | — |  | (448) |
Repurchase of common stock | — |  | — |  | (1,147) |  | — |  | — |  | — |  | (1,147) |
Distributions to noncontrolling interests | — |  | — |  | — |  | — |  | — |  | (13) |  | (13) |
Benefit plan activity | — |  | 24 |  | — |  | (4) |  | — |  | — |  | 20 |
March 31, 2024 | $ | 7 |  | 19,674 |  | (20,489) |  | 30,846 |  | (312) |  | 1,067 |  | 30,793 |

| Shares
| Three Months Ended March 31
| Common Stock Issued | Treasury Stock
December 31, 2024 | 656,987,861 |  | 248,594,923 |
Repurchase of common stock | — |  | 1,996,593 |
Shares issued—share-based compensation | 1,185,541 |  | — |
March 31, 2025 | 658,173,402 |  | 250,591,516 |
December 31, 2023 | 654,842,101 |  | 224,377,439 |
Repurchase of common stock | — |  | 7,955,117 |
Shares issued—share-based compensation | 1,442,590 |  | — |
March 31, 2024 | 656,284,691 |  | 232,332,556 |
See Notes to Consolidated Financial Statements.

5

Table of Contents

Notes to Consolidated Financial Statements | Phillips 66

Note 1—Interim Financial Information
The unaudited interim financial information presented in the financial statements included in this report is prepared in accordance with generally accepted accounting principles in the United States (GAAP) and includes all known accruals and adjustments necessary, in the opinion of management, for a fair presentation of the consolidated financial position of Phillips 66 and its results of operations and cash flows for the periods presented. Unless otherwise specified, all such adjustments are of a normal and recurring nature. Certain notes and other information have been condensed or omitted from the interim financial statements included in this report. Therefore, these interim financial statements should be read in conjunction with the consolidated financial statements and notes included in our 2024 Annual Report on Form 10-K. The results of operations for the three months ended March 31, 2025, are not necessarily indicative of the results expected for the full year.
Certain prior period financial information has been recast for comparability. See Note 19—Segment Disclosures and Related Information, for further information regarding recast prior period financial information.
6

Table of Contents
Note 2—Restructuring
Los Angeles Refinery
In October 2024, we announced our intention to cease operations at our Los Angeles Refinery in the fourth quarter of 2025, and we are evaluating potential future uses of the property. As a result of this decision, the following impacts were recorded in our Refining segment:
•We assessed the Los Angeles Refinery asset group for impairment and concluded that the carrying value of the asset group was recoverable. However, the estimated useful lives of the Los Angeles Refinery assets were shortened to reflect the plan to cease the use of the assets in the fourth quarter of 2025. As of March 31, 2025, the $1,019 million carrying value of the net properties, plants and equipment (PP&E) and intangible assets will be depreciated through the fourth quarter of 2025 to the estimated salvage value of $241 million. Total depreciation related to the Los Angeles Refinery assets for the three months ended March 31, 2025 was $270 million, including $246 million of accelerated depreciation. This accelerated depreciation is included within the “Depreciation and amortization” line item on our consolidated statement of income for the three months ended March 31, 2025.
•Our asset retirement obligations (AROs) at the Los Angeles Refinery were $276 million as of March 31, 2025, primarily reflecting asbestos abatement and decommissioning of assets. The estimation of asset retirement obligations requires significant judgment and is subject to changes in the underlying assumptions. Depreciation of the related capitalized asset retirement costs also will be recorded through the fourth quarter of 2025, and the amount for the three months ended March 31, 2025, is reflected in the accelerated depreciation discussed above.
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Note 3—Business Combinations
Midstream Acquisitions
On July 1, 2024, we acquired Pinnacle Midland Parent LLC to expand our natural gas gathering and processing operations in the Permian Basin for cash consideration of $565 million. For this acquisition, we provisionally recorded $325 million of PP&E, including finance lease right of use assets; $256 million of amortizable intangible assets, primarily customer relationships; $21 million of goodwill; $18 million of net working capital deficit; $13 million of AROs; and $6 million of finance lease liabilities. The fair values of the assets acquired and liabilities assumed are preliminary and subject to change until we finalize the accounting for this acquisition.
Subsequent Midstream Acquisition
On April 1, 2025, we acquired all issued and outstanding equity interests in each of EPIC Y-Grade GP, LLC and EPIC Y-Grade, LP, together with their respective subsidiaries, which own various long haul natural gas liquids pipelines, fractionation facilities and distribution systems, for cash consideration of $2.2 billion, net of cash acquired.
The transaction will be accounted for as a business combination under FASB ASC 805 using the acquisition method, which requires assets acquired and liabilities assumed to be measured at their acquisition date fair values. We are currently in the process of finalizing the initial accounting for the transaction and provisional fair value measurements will be made in the second quarter of 2025. We may adjust the measurements in subsequent periods, up to one year from the acquisition date, as we identify additional information to complete the necessary analysis.
Marketing and Specialties Acquisition
On October 1, 2024, we acquired a marketing business on the U.S. West Coast for total consideration of $68 million. These operations were acquired to support the placement of renewable diesel produced by the Rodeo Renewable Energy Complex (Rodeo Complex). For this acquisition, we provisionally recorded $20 million of amortizable intangible assets, primarily customer relationships; $62 million of PP&E, including finance lease right of use assets; $31 million of net working capital; and $45 million of finance lease liabilities. The fair values of the assets acquired and liabilities assumed are preliminary and subject to change until we finalize our accounting for this acquisition.
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Note 4—Sales and Other Operating Revenues
Disaggregated Revenues
The following tables present our disaggregated sales and other operating revenues:

| Millions of Dollars
| Three Months Ended March 31 |  |
| 2025 |  |  | 2024 |  |  |  |
Product Line and Services |  |  |  |  |  |
Refined petroleum products and renewable fuels | $ | 22,249 |  |  | 25,739 |  |  |  |
Crude oil resales | 3,102 |  |  | 5,578 |  |  |  |
Natural gas liquids (NGL) and natural gas | 4,506 |  |  | 3,334 |  |  |  |
Services and other* | 573 |  |  | 1,160 |  |  |  |
Consolidated sales and other operating revenues | $ | 30,430 |  |  | 35,811 |  |  |  |
Geographic Location** |  |  |  |  |  |
United States | $ | 24,159 |  |  | 28,377 |  |  |  |
United Kingdom | 2,962 |  |  | 3,890 |  |  |  |
Germany | 1,218 |  |  | 1,303 |  |  |  |
Other countries | 2,091 |  |  | 2,241 |  |  |  |
Consolidated sales and other operating revenues | $ | 30,430 |  |  | 35,811 |  |  |  |
* Includes derivatives-related activities. See Note 14—Derivatives and Financial Instruments, for additional information.
** Sales and other operating revenues are attributable to countries based on the location of the operations generating the revenues.

Contract-Related Assets and Liabilities
At March 31, 2025, and December 31, 2024, receivables from contracts with customers were $7,992 million and $8,615 million, respectively. Significant noncustomer balances, such as buy/sell receivables and excise tax receivables, were excluded from these amounts.
Our contract-related assets also include payments we make to our marketing customers related to incentive programs. An incentive payment is initially recognized as an asset and subsequently amortized as a reduction to revenue over the contract term, which generally ranges from 5 to 15 years. At March 31, 2025, and December 31, 2024, our asset balances related to such payments were $659 million and $643 million, respectively.
Our contract liabilities primarily represent advances from our customers prior to product or service delivery. At March 31, 2025, and December 31, 2024, contract liabilities were $203 million and $232 million, respectively.
Remaining Performance Obligations
Most of our contracts with customers are spot contracts or term contracts with only variable consideration. We do not disclose remaining performance obligations for these contracts as the expected duration is one year or less or because the variable consideration has been allocated entirely to an unsatisfied performance obligation. We also have certain contracts in our Midstream segment that include minimum volume commitments with fixed pricing. At March 31, 2025, the remaining performance obligations related to these minimum volume commitment contracts amounted to $579 million. This amount excludes variable consideration and estimates of variable rate escalation clauses in our contracts with customers, and is expected to be recognized through 2035 with a weighted average remaining life of three years as of March 31, 2025.
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Note 5—Credit Losses
We are exposed to credit losses primarily through our sales of refined petroleum products, renewable fuels, renewable feedstocks, crude oil, NGL and natural gas. We assess each counterparty’s ability to pay for the products we sell by conducting a credit review. The credit review considers our expected billing exposure and timing for payment and the counterparty’s established credit rating or our assessment of the counterparty’s creditworthiness based on our analysis of their financial statements when a credit rating is not available. We also consider contract terms and conditions, country and political risk, and business strategy in our evaluation. A credit limit is established for each counterparty based on the outcome of this review. We may require collateralized asset support or a prepayment to mitigate credit risk.
We monitor our ongoing credit exposure through active review of counterparty balances against contract terms and due dates. Our activities include timely account reconciliations, dispute resolution and payment confirmations. We may employ collection agencies and legal counsel to pursue recovery of defaulted receivables. In addition, when events and circumstances arise that may affect certain counterparties’ abilities to fulfill their obligations, we enhance our credit monitoring, and we may seek collateral to support some transactions or require prepayments from higher-risk counterparties.
At March 31, 2025, and December 31, 2024, we reported $10,221 million and $11,033 million of accounts and notes receivable, net of allowances of $70 million for both periods. Based on an aging analysis at March 31, 2025, more than 95% of our accounts receivable were outstanding less than 60 days.
We are also exposed to credit losses from off-balance sheet exposures, such as guarantees of joint venture debt and accounts receivables sold under a securitization facility, as well as standby letters of credit. See Note 11—Debt, Note 12—Guarantees, and Note 13—Contingencies and Commitments, for more information on these off-balance sheet exposures.
Note 6—Inventories
Inventories consisted of the following:

| Millions of Dollars
| March 31 2025 |  | December 31 2024
Crude oil and products | $ | 4,791 |  |  | 3,547 |
Materials and supplies | 449 |  |  | 448 |
| $ | 5,240 |  |  | 3,995 |

Inventories valued on the last-in, first-out (LIFO) basis totaled $4,694 million and $3,443 million at March 31, 2025, and December 31, 2024, respectively. The estimated excess of current replacement cost over LIFO cost of inventories amounted to approximately $5.4 billion and $4.9 billion at March 31, 2025, and December 31, 2024, respectively.
Certain planned reductions in inventory that are not expected to be replaced by the end of the year cause liquidations of LIFO inventory values. LIFO liquidations did not have a material impact on net income for the three months ended March 31, 2025 and 2024.
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Note 7—Investments, Loans and Long-Term Receivables
Equity Investments
Dakota Access, LLC (Dakota Access) and Energy Transfer Crude Oil Company, LLC (ETCO)
In 2020, the trial court presiding over litigation brought by the Standing Rock Sioux Tribe (the Tribe) ordered the U.S. Army Corps of Engineers (USACE) to prepare an Environmental Impact Statement (EIS) addressing an easement under Lake Oahe in North Dakota. The trial court later vacated the easement. Although the easement is vacated, the USACE has no plans to stop pipeline operations while it proceeds with the EIS, and the Tribe’s request for a shutdown was denied in May 2021. In June 2021, the trial court dismissed the litigation entirely. Once the EIS is completed, new litigation or challenges may be filed.
In February 2022, the U.S. Supreme Court (the Supreme Court) denied Dakota Access’ writ of certiorari requesting the Supreme Court to review the trial court’s decision to order the EIS and vacate the easement. Therefore, the requirement to prepare the EIS stood. Also in February 2022, the Tribe withdrew as a cooperating agency, causing the USACE to halt the EIS process while the USACE engaged with the Tribe on their reasons for withdrawing.
The draft EIS process resumed in August 2022, and in September 2023, the USACE published its draft EIS for public comment. The USACE identified five potential outcomes but did not indicate which one it preferred. The options comprise two “no action” alternatives where the USACE would deny an easement to Dakota Access and require it to shut down the pipeline and either remove the pipe from under Lake Oahe or allow the pipeline to be abandoned-in-place under the lake. The USACE also identified three “action” alternatives; two of them contemplate that the USACE would reissue the easement to Dakota Access under essentially the same terms as 2017 with either the same or a larger volume of oil allowed through the pipeline, while the third alternative would require decommissioning of the current pipeline and construction of a new line 39 miles upstream from the current location.
The public comment period concluded on December 13, 2023. The USACE plans to review the comments and issue its final EIS in early 2026. The Record of Decision will follow within 30 to 60 days after the issuance of the final EIS. The final EIS must be completed before the USACE can reauthorize the easement for the pipeline. If reauthorization occurs, new litigation challenging the reauthorization may be filed.
In October 2024, the Tribe filed another lawsuit against the USACE in federal district court in Washington, D.C., again challenging USACE’s allowance of pipeline operations while the EIS process proceeds. In this lawsuit, the Tribe purports to introduce new evidence regarding the pipeline’s proximity to a reservoir and attempts to relitigate arguments about the need for injunctive relief to support its position that the Supreme Court should halt pipeline operations. A consortium of 13 states has joined Dakota Access as intervenors. The consortium argues that the pipeline reduces pollution compared to other modes of transportation and that Dakota Access is integral to the health of regional energy and agriculture markets. The Tribe’s prior request for a shutdown was denied in May 2021. This latest lawsuit seeking a shutdown does not change the current deadline for the issuance of the final EIS. Motions to Dismiss the latest lawsuit were filed by USACE, Dakota Access, and Intervenors and opposed by the Tribe. The parties are awaiting the district court’s decision. On March 19, 2025, the Tribe filed a notice in support of its latest lawsuit, indicating three additional facts for the district court to consider when making its ruling on the lawsuit. These facts relate to events regarding Energy Transfer LP’s conduct and third-party actions against it.
Dakota Access and ETCO have guaranteed repayment of senior unsecured notes issued by a wholly owned subsidiary of Dakota Access. On April 1, 2024, Dakota Access’ wholly owned subsidiary repaid $1 billion aggregate principal amount of its outstanding senior notes upon maturity. We funded our 25% share of the repayment, or $250 million, with a capital contribution of $171 million in March 2024 and $79 million of distributions we elected not to receive from Dakota Access in the first quarter of 2024. At March 31, 2025, the aggregate principal amount outstanding of Dakota Access’ senior unsecured notes was $850 million.
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In addition, Phillips 66 Partners LP (Phillips 66 Partners), a wholly owned subsidiary of Phillips 66, and its co-venturers in Dakota Access also provided a Contingent Equity Contribution Undertaking (CECU) in conjunction with the notes offering. Under the CECU, the co-venturers may be severally required to make proportionate equity contributions to Dakota Access if there is an unfavorable final judgment in the above-mentioned ongoing litigation. At March 31, 2025, our 25% share of the maximum potential equity contributions under the CECU was approximately $215 million. If the pipeline is required to cease operations, it may have a material adverse effect on our results of operations and cash flows. Should operations cease and Dakota Access and ETCO not have sufficient funds to pay its expenses, we also could be required to support our 25% share of the ongoing expenses, including scheduled interest payments on the notes of approximately $10 million annually, in addition to the potential obligations under the CECU at March 31, 2025.
At March 31, 2025, the aggregate book value of our investments in Dakota Access and ETCO was $875 million.
OnCue Holdings, LLC (OnCue)
We hold a 50% interest in OnCue, a joint venture that owns and operates retail convenience stores. We fully guarantee various debt agreements of OnCue and our co-venturer does not participate in the guarantees. This entity is considered a variable interest entity (VIE) because our debt agreements resulted in OnCue not being exposed to all potential losses. We have determined that we are not the primary beneficiary because we do not have the power to direct the activities that most significantly impact economic performance. At March 31, 2025, our maximum exposure to loss was $248 million, which represented the book value of our investment in OnCue of $190 million and guaranteed debt obligations of $58 million.
Investment Dispositions
On January 31, 2025, we sold our 49% ownership interest in Coop Mineraloel AG (Coop) and settled the foreign currency forward contracts entered into in connection with the asset sale. We received cash proceeds of $1.2 billion, consisting of a sales price of $1.15 billion and a final dividend relating to financial year 2024 of $92 million from Coop that was paid on January 30, 2025. We recognized a before-tax gain of $1 billion associated with the sale in the “Net gain on dispositions” line item on our consolidated statement of income for the three months ended March 31, 2025, which is reported in our M&S segment. The final dividend of $92 million is included within the “Cash Flows from Operating Activities” section of our consolidated statement of cash flows.
On January 30, 2025, DCP Midstream, LP (DCP LP) sold its 25% ownership interest in Gulf Coast Express Pipeline LLC for cash proceeds of $853 million. We recognized a before-tax gain of $68 million, which is included in the “Net gain on dispositions” line item on our consolidated statement of income for the three months ended March 31, 2025, and is reported in our Midstream segment.
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Note 8—Properties, Plants and Equipment
Our investment in PP&E and the associated accumulated depreciation and amortization (Accum. D&A) balances were as follows:

| Millions of Dollars
| March 31, 2025 |  | December 31, 2024
| Gross PP&E |  | Accum. D&A |  | Net PP&E |  | Gross PP&E |  | Accum. D&A |  | Net PP&E
Midstream | $ | 26,342 |  |  | 5,003 |  |  | 21,339 |  |  | 26,187 |  |  | 4,820 |  |  | 21,367 |
Chemicals | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Refining | 22,527 |  |  | 12,437 |  |  | 10,090 |  |  | 22,274 |  |  | 11,991 |  |  | 10,283 |
Marketing and Specialties | 2,138 |  |  | 1,307 |  |  | 831 |  |  | 2,091 |  |  | 1,267 |  |  | 824 |
Renewable Fuels | 3,725 |  |  | 1,692 |  |  | 2,033 |  |  | 3,716 |  |  | 1,669 |  |  | 2,047 |
Corporate and Other | 1,676 |  |  | 1,003 |  |  | 673 |  |  | 1,688 |  |  | 945 |  |  | 743 |
| $ | 56,408 |  |  | 21,442 |  |  | 34,966 |  |  | 55,956 |  |  | 20,692 |  |  | 35,264 |

See Note 2—Restructuring, for information regarding our intention to cease operations at our Los Angeles Refinery. See Note 9—Impairments, for information regarding PP&E impairments.
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Note 9—Impairments

| Millions of Dollars
| Three Months Ended March 31
| 2025 |  |  | 2024 |  |  |  |
Midstream | $ | — |  |  | 59 |  |  |  |
Refining | 1 |  |  | 105 |  |  |  |
Corporate and Other | 25 |  |  | 1 |  |  |  |
Total impairments | $ | 26 |  |  | 165 |  |  |  |

In the first quarter of 2024, we recorded before-tax impairments totaling $163 million related to certain crude oil processing and logistics assets in California, of which $104 million was reported in our Refining segment and $59 million was reported in our Midstream segment.
These impairment charges are included within the “Impairments” line item on our consolidated statement of income. See Note 15—Fair Value Measurements, for additional information on the determination of fair value used to record these impairments.
Note 10—Earnings Per Share
The numerator of basic earnings per share (EPS) is net income attributable to Phillips 66, adjusted for noncancelable dividends paid on unvested share-based employee awards during the vesting period (participating securities). The denominator of basic EPS is the sum of the daily weighted-average number of common shares outstanding during the periods presented and fully vested stock and unit awards that have not yet been issued as common stock. The numerator of diluted EPS is also based on net income attributable to Phillips 66, which is reduced by dividend equivalents paid on participating securities for which the dividends are more dilutive than the participation of the awards in the earnings of the periods presented. To the extent unvested stock, unit or option awards and vested unexercised stock options are dilutive, they are included with the weighted-average common shares outstanding in the denominator. Treasury stock is excluded from the denominator in both basic and diluted EPS.

| Three Months Ended March 31 |  |
| 2025 |  | 2024 |  |  |
| Basic | Diluted |  | Basic | Diluted |  |  |  |  |
Amounts Attributed to Phillips 66 Common Stockholders (millions): |  |  |  |  |  |  |  |  |  |
Net Income Attributable to Phillips 66 | 487 |  | 487 |  |  | 748 |  | 748 |  |  |  |  |  |
Income allocated to participating securities | (2) |  | (2) |  |  | (2) |  | (1) |  |  |  |  |  |
Net income available to common stockholders | $ | 485 |  | 485 |  |  | 746 |  | 747 |  |  |  |  |  |
Weighted-average common shares outstanding (thousands): | 407,926 |  | 409,182 |  |  | 427,165 |  | 428,959 |  |  |  |  |  |
Effect of share-based compensation | 1,256 |  | 1,323 |  |  | 1,794 |  | 2,947 |  |  |  |  |  |
Weighted-average common shares outstanding—EPS | 409,182 |  | 410,505 |  |  | 428,959 |  | 431,906 |  |  |  |  |  |
Earnings Per Share of Common Stock (dollars) | $ | 1.19 |  | 1.18 |  |  | 1.74 |  | 1.73 |  |  |  |  |  |

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Note 11—Debt

Senior Notes and Term Loan Issuances and Repayments
Issuances
On February 28, 2024, Phillips 66 Company, a wholly owned subsidiary of Phillips 66, issued $1.5 billion aggregate principal amount of senior unsecured notes that are fully and unconditionally guaranteed by Phillips 66. The senior unsecured notes issuance consisted of:
•$600 million aggregate principal amount of 5.250% Senior Notes due 2031 (2031 Notes).
•$400 million aggregate principal amount of 5.300% Senior Notes due 2033 (Additional 2033 Notes).
•$500 million aggregate principal amount of 5.650% Senior Notes due 2054 (2054 Notes).
Interest on the 2031 Notes and 2054 Notes is payable semi-annually on June 15 and December 15 of each year and commenced on June 15, 2024. Interest on the Additional 2033 Notes is payable semi-annually on June 30 and December 30 of each year and commenced on June 30, 2024.
Repayments
On February 18, 2025, upon maturity, Phillips 66 Partners repaid its 3.605% Senior Notes due February 2025 with an aggregate principal amount of $59 million.
On March 29, 2024, DCP LP redeemed $300 million of its 5.375% Senior Notes due July 2025. After the redemption, an aggregate principal amount of $525 million remained outstanding.
On March 4, 2024, Phillips 66 Company repaid $700 million of the $1.25 billion borrowed under its delayed draw term loan that matures in June 2026.
On February 15, 2024, upon maturity, Phillips 66 repaid its 0.900% senior notes due February 2024 with an aggregate principal amount of $800 million.
Accounts Receivable Securitization
On September 30, 2024, Phillips 66 Company entered into a 364-day, $500 million accounts receivable securitization facility (the Receivables Securitization Facility). Under the Receivables Securitization Facility, Phillips 66 Company sells or contributes on an ongoing basis, certain of its receivables, together with related security and interests in the proceeds thereof, to its wholly owned subsidiary, Phillips 66 Receivables LLC (P66 Receivables), a consolidated and bankruptcy-remote special purpose entity created for the sole purpose of transacting under the Receivables Securitization Facility. Under the Receivables Securitization Facility, P66 Receivables may borrow and incur indebtedness from, and/or sell certain receivables in an amount not to exceed $500 million in the aggregate, and will secure its obligations with a pledge of undivided interests in such receivables, together with related security and interests in the proceeds thereof, to PNC Bank, National Association, as Administrative Agent, for the benefit of the secured parties thereunder.
Sales of accounts receivables under the Receivables Securitization Facility meet the sale criteria under ASC 860, Transfers and Servicing, and are derecognized from the consolidated balance sheet. P66 Receivables guarantees payment, in full, for accounts receivables sold to the purchasers. For the three months ended March 31, 2025, we sold $130 million of accounts receivables for cash proceeds under the Receivables Securitization Facility. We recognized an immaterial charge associated with the transfer of financial assets, which is included as a component within the line item “Selling, general and administrative expense” on our consolidated statement of income during the three months ended March 31, 2025.
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At March 31, 2025, we had utilized $130 million of our $500 million Receivable Securitization Facility from sold accounts receivables not yet remitted to the purchaser. Additionally, we had no outstanding borrowings at March 31, 2025. Therefore, at March 31, 2025, we had unused capacity of $370 million. At December 31, 2024, we had utilized the full $500 million of our Receivables Securitization Facility from $125 million of sold accounts receivables not yet remitted to the purchaser and $375 million of outstanding borrowings.
On April 1, 2025, Phillips 66 Company amended the Receivables Securitization Facility to, among other things, increase the maximum size of the Receivables Securitization Facility from $500 million to $1 billion.
Credit Facilities and Commercial Paper
Phillips 66 and Phillips 66 Company
On January 13, 2025, we entered into a $200 million uncommitted credit facility (the 2025 Uncommitted Facility) with Phillips 66 Company as the borrower and Phillips 66 as the guarantor. The 2025 Uncommitted Facility contains covenants and events of default customary for unsecured uncommitted facilities. The 2025 Uncommitted Facility has no commitment fees or compensating balance requirements. Outstanding borrowings under the 2025 Uncommitted Facility bear interest at a rate of either (a) the adjusted term SOFR plus the applicable margin, (b) the adjusted daily simple SOFR plus the applicable margin or (c) the base rate, in each case plus the applicable margin. Each borrowing matures six months from the date of such borrowing. We may at any time prepay outstanding borrowings, in whole or in part, without premium or penalty. At March 31, 2025, no amount had been drawn under the 2025 Uncommitted Facility.
On June 25, 2024, we entered into a $400 million uncommitted credit facility (the Uncommitted Facility) with Phillips 66 Company as the borrower and Phillips 66 as the guarantor. The Uncommitted Facility contains covenants and events of default customary for unsecured uncommitted facilities. The Uncommitted Facility has no commitment fees or compensating balance requirements. Outstanding borrowings under the Uncommitted Facility bear interest at a rate of either (a) the adjusted term SOFR, (b) the adjusted daily simple SOFR or (c) the reference rate, in each case plus the applicable margin. Each borrowing matures six months from the date of such borrowing. We may at any time prepay outstanding borrowings, in whole or in part, without premium or penalty. At March 31, 2025, no amount had been drawn under the 2024 Uncommitted Facility, while at December 31, 2024, the entire $400 million had been drawn.
On February 28, 2024, we entered into a new $5 billion revolving credit agreement (the Facility) with Phillips 66 Company as the borrower and Phillips 66 as the guarantor and a scheduled maturity date of February 28, 2029. The Facility replaced our previous $5 billion revolving credit facility dated as of June 23, 2022, with Phillips 66 Company as the borrower and Phillips 66 as the guarantor, and the previous revolving credit facility was terminated. The Facility contains customary covenants similar to the previous revolving credit facility, including a maximum consolidated net debt-to-capitalization ratio of 65% as of the last day of each fiscal quarter. The Facility has customary events of default, such as nonpayment of principal when due; nonpayment of interest, fees or other amounts after grace periods; and violation of covenants. We may at any time prepay outstanding borrowings under the Facility, in whole or in part, without premium or penalty. We have the option to increase the overall capacity to $6 billion, subject to certain conditions. We also have the option to extend the scheduled maturity of the Facility for up to two additional one-year terms, subject to, among other things, the consent of the lenders holding the majority of the commitments and of each lender extending its commitment. Outstanding borrowings under the Facility bear interest at either: (a) the adjusted term SOFR (as described in the Facility) in effect from time to time plus the applicable margin; or (b) the reference rate (as described in the Facility) plus the applicable margin. The pricing levels for the commitment fee and interest-rate margins are determined based on the ratings in effect for our senior unsecured long-term debt from time to time. At March 31, 2025, and December 31, 2024, no amount had been drawn under the Facility.
Phillips 66 also has a $5 billion uncommitted commercial paper program for short-term working capital needs that is supported by the Facility. Commercial paper maturities are contractually limited to less than one year. At March 31, 2025, no borrowings were outstanding under this program, while at December 31, 2024, $435 million of commercial paper had been issued under this program.
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DCP Midstream Class A Segment
On March 15, 2024, DCP LP terminated its $1.4 billion credit facility and its accounts receivable securitization facility that previously provided for up to $350 million of borrowing capacity. In conjunction with the termination of these facilities, DCP LP repaid $25 million in borrowings outstanding under its $1.4 billion credit facility and $350 million of borrowings outstanding under its accounts receivable securitization facility during the three months ended March 31, 2024.
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Note 12—Guarantees
At March 31, 2025, we were liable for certain contingent obligations under various contractual arrangements as described below. We recognize a liability for the fair value of our obligation as a guarantor for newly issued or modified guarantees. Unless the carrying amount of the liability is noted below, we have not recognized a liability either because the guarantees were issued prior to December 31, 2002, or because the fair value of the obligation is immaterial. In addition, unless otherwise stated, we are not currently performing with any significance under the guarantees and expect future performance to be either immaterial or have only a remote chance of occurrence.
Lease Residual Value Guarantees
Under the operating lease agreement for our headquarters facility in Houston, Texas, we have the option, at the end of the lease term in September 2025, to request to renew the lease, purchase the facility or assist the lessor in marketing it for resale. We have a residual value guarantee associated with the operating lease agreement with a maximum potential future exposure of $514 million at March 31, 2025. We also have residual value guarantees associated with railcar, airplane and truck leases with maximum potential future exposures totaling $176 million. These leases have remaining terms of one to ten years.
Guarantees of Joint Venture Obligations
In March 2019, Phillips 66 Partners and its co-venturers in Dakota Access provided a CECU in conjunction with a senior unsecured notes offering. See Note 7—Investments, Loans and Long-Term Receivables, for additional information regarding Dakota Access and the CECU.
At March 31, 2025, we also had other guarantees outstanding primarily for our portion of certain joint venture debt, which have remaining terms of up to five years. The maximum potential future exposures under these guarantees were approximately $293 million. Payment would be required if a joint venture defaults on its obligations.
Indemnifications
Over the years, we have entered into various agreements to sell ownership interests in certain corporations, joint ventures and assets that gave rise to indemnifications. Agreements associated with these sales include indemnifications for taxes, litigation, environmental liabilities, permits and licenses, employee claims, and real estate tenant defaults. The provisions of these indemnifications vary greatly. The majority of these indemnifications are related to environmental issues, which generally have indefinite terms and potentially unlimited exposure. At March 31, 2025, and December 31, 2024, the carrying amount of recorded indemnifications was $122 million and $125 million, respectively.
We amortize the indemnification liability over the relevant time period, if one exists, based on the facts and circumstances surrounding each type of indemnity. In cases where the indemnification term is indefinite, we will reverse the liability when we have information to support the reversal. Although it is reasonably possible future payments may exceed amounts recorded, due to the nature of the indemnifications, it is not possible to make a reasonable estimate of the maximum potential amount of future payments.
At March 31, 2025, and December 31, 2024, environmental accruals for known contamination of $98 million and $100 million, respectively, were included in the carrying amount of the recorded indemnifications noted above. These environmental accruals were primarily included in the “Asset retirement obligations and accrued environmental costs” line item on our consolidated balance sheet. For additional information about environmental liabilities, see Note 13—Contingencies and Commitments.
Additionally, P66 Receivables has guaranteed all borrowings and receivables sold under our Receivables Securitization Facility. At March 31, 2025, $127 million of the sold accounts receivable remained uncollected, which represents our maximum potential future exposure under the guarantee associated with the Receivables Securitization Facility. See Note 11—Debt, for information regarding our Receivables Securitization Facility.
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Indemnification and Release Agreement
In 2012, in connection with our separation from ConocoPhillips, we entered into an Indemnification and Release Agreement. This agreement governs the treatment between ConocoPhillips and us of matters relating to indemnification, insurance, litigation responsibility and management, and litigation document sharing and cooperation arising in connection with the separation. Generally, the agreement provides for cross indemnities principally designed to place financial responsibility for the obligations and liabilities of our business with us and financial responsibility for the obligations and liabilities of ConocoPhillips’ business with ConocoPhillips. The agreement also establishes procedures for handling claims subject to indemnification and related matters.
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Note 13—Contingencies and Commitments
A number of lawsuits involving a variety of claims that arose in the ordinary course of business have been filed against us or are subject to indemnifications provided by us. We also may be required to remove or mitigate the effects on the environment of the placement, storage, disposal or release of certain chemical, mineral and petroleum substances at various active and inactive sites. We regularly assess the need for financial recognition or disclosure of these contingencies. In the case of all known contingencies (other than those related to income taxes), we accrue a liability when the loss is probable and the amount is reasonably estimable. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. We do not reduce these liabilities for potential insurance or third-party recoveries. If applicable, we accrue receivables for probable insurance or other third-party recoveries. In the case of income tax-related contingencies, we use a cumulative probability-weighted loss accrual in cases where sustaining a tax position is uncertain.
Other than with respect to the legal matters described herein, based on currently available information, we believe it is remote that future costs related to known contingent liability exposures will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures. Estimates particularly sensitive to future changes include contingent liabilities recorded for environmental remediation, tax and legal matters. Estimated future environmental remediation costs are subject to change due to such factors as the uncertain magnitude of cleanup costs, the unknown time and extent of such remedial actions that may be required, and the determination of our liability in proportion to that of other potentially responsible parties. Estimated future costs related to tax and legal matters are subject to change as events evolve and as additional information becomes available during the administrative and litigation processes.
Environmental
We are subject to international, federal, state and local environmental laws and regulations. When we prepare our consolidated financial statements, we record accruals for environmental liabilities based on management’s best estimates, using information available at the time. We measure estimates and base contingent liabilities on currently available facts, existing technology and presently enacted laws and regulations, taking into account stakeholder and business considerations. When measuring contingent environmental liabilities, we also consider our prior experience in remediation of contaminated sites, other companies’ cleanup experience, and data released by the Environmental Protection Agency (EPA) or other organizations. We consider unasserted claims in our determination of environmental liabilities, and we accrue them in the period they are both probable and reasonably estimable.
Although liability for environmental remediation costs is generally joint and several for federal sites and frequently so for state sites, we are usually only one of many companies alleged to have liability at a particular site. Due to such joint and several liabilities, we could be responsible for all cleanup costs related to any site at which we have been designated as a potentially responsible party. We have been successful to date in sharing cleanup costs with other financially sound companies. Many of the sites for which we are potentially responsible are still under investigation by the EPA or the state agencies concerned. Prior to actual cleanup, those potentially responsible normally assess the site conditions, apportion responsibility and determine the appropriate remediation. In some instances, we may have no liability or may attain a settlement of liability. Where it appears that other potentially responsible parties may be financially unable to bear their proportional share, we consider this inability in estimating our potential liability, and we adjust our accruals accordingly. As a result of various acquisitions in the past, we assumed certain environmental obligations. Some of these environmental obligations are mitigated by indemnifications made by others for our benefit, although some of the indemnifications are subject to dollar and time limits.
We are currently participating in environmental assessments and cleanups at numerous federal Superfund and comparable state sites. After an assessment of environmental exposures for cleanup and other costs, we make accruals on an undiscounted basis (except those pertaining to sites acquired in a business combination, which we record on a discounted basis) for planned investigation and remediation activities for sites where it is probable future costs will be incurred and these costs can be reasonably estimated. At March 31, 2025, our total environmental accruals were $435 million, compared with $439 million at December 31, 2024. We expect to incur a substantial amount of these expenditures within the next 30 years. We have not reduced these accruals for possible insurance recoveries. In the future, we may be involved in additional environmental assessments, cleanups and proceedings.
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Legal Proceedings
Our legal organization applies its knowledge, experience and professional judgment to the specific characteristics of our cases, employing a litigation management process to manage and monitor the legal proceedings against us. Our process facilitates the early evaluation and quantification of potential exposures in individual cases and enables the tracking of those cases that have been scheduled for trial and/or mediation. Based on professional judgment and experience in using these litigation management tools and available information about current developments in all our cases, our legal organization regularly assesses the adequacy of current accruals and determines if adjustment of existing accruals, or establishment of new accruals, is required.
Propel Fuels Litigation
In late 2017, as part of Phillips 66 Company’s evaluation of various opportunities in the renewable fuels business, Phillips 66 Company engaged with Propel Fuels, Inc. (Propel Fuels), a California company that distributes E85 and other alternative fuels through fueling kiosks. Ultimately, the parties were not able to reach an agreement and negotiations were terminated in August 2018. On February 17, 2022, Propel Fuels filed a lawsuit in the Superior Court of California, County of Alameda (the Propel Court), alleging that Phillips 66 Company misappropriated trade secrets related to Propel Fuels’ renewable fuels business during and after due diligence. On October 16, 2024, a jury returned a verdict against Phillips 66 Company for $604.9 million in compensatory damages and issued a willfulness finding. In 2025, the Propel Court is expected to rule on motions filed by Propel Fuels seeking exemplary damages and attorneys’ fees. Propel Fuels asked the Propel Court to grant treble damages and Phillips 66 Company filed a brief in opposition to that request. A hearing on the exemplary damages was held on March 4, 2025. Also in 2025, the Propel Court is expected to rule on motions to be filed by Phillips 66 Company for a judgment in its favor as a matter of law, or in the alternative to reduce the jury’s verdict or to grant a new trial. Phillips 66 Company denies any wrongdoing and intends to vigorously defend its position. As a result of the jury verdict in October 2024, the Company recorded an accrual of $604.9 million during the third quarter of 2024, which was reported in the M&S segment. The accrued amount is reflected as “Other liabilities and deferred credits” on our consolidated balance sheet as of March 31, 2025, and December 31, 2024. However, it is reasonably possible that the estimate of the loss could change based on the progression of the case, including the appeals process. Because of the uncertainties associated with ongoing litigation, we are unable to estimate the range of reasonably possible loss that may be attributable to exemplary damages, if any, in excess of the amount accrued. If information were to become available that would allow us to reasonably estimate a range of potential exposure in an amount higher or lower than the amount already accrued, we would adjust our accrued liabilities accordingly. While Phillips 66 Company believes the jury verdict is not legally or factually supported and intends to pursue post-judgment remedies and file an appeal, there can be no assurances that such defense efforts will be successful. To the extent Phillips 66 Company is required to pay exemplary damages, it may have a material adverse effect on our financial position and results of operations.
Other Contingencies
We have contingent liabilities resulting from throughput agreements with pipeline and processing companies not associated with financing arrangements. Under these agreements, we may be required to provide any such company with additional funds through advances and penalties for fees related to throughput capacity not utilized.
At March 31, 2025, we had performance obligations secured by letters of credit and bank guarantees of $778 million related to various purchase and other commitments incident to the ordinary conduct of business.
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Note 14—Derivatives and Financial Instruments
Derivative Instruments
We use financial and commodity-based derivative contracts to manage exposures to fluctuations in commodity prices, interest rates and foreign currency exchange rates, or to capture market opportunities. Because we do not apply hedge accounting for commodity derivative contracts, all realized and unrealized gains and losses from commodity derivative contracts are recognized in our consolidated statement of income. Gains and losses from derivative contracts held for trading not directly related to our physical business are reported net in the “Other income” line item on our consolidated statement of income. Realized and unrealized gains on the foreign currency derivative entered into in connection with the sale of our 49% ownership interest in Coop are reported in the “Net gain on dispositions” line item on our consolidated statement of income. Cash flows from all of our commodity derivative activity for the periods presented appear in the operating section on our consolidated statement of cash flows.
Purchase and sales contracts with firm minimum notional volumes for commodities that are readily convertible to cash are recorded on our consolidated balance sheet as derivatives unless the contracts are eligible for, and we elect, the normal purchases and normal sales exception, whereby the contracts are recorded on an accrual basis. We generally apply the normal purchases and normal sales exception to eligible crude oil, refined petroleum product, NGL, natural gas, renewable feedstocks, and power commodity contracts to purchase or sell quantities we expect to use or sell in the normal course of business. All other derivative instruments are recorded at fair value on our consolidated balance sheet. For further information on the fair value of derivatives, see Note 15—Fair Value Measurements.
Commodity Derivative Contracts
We sell into or receive supply from the worldwide crude oil, refined petroleum product, NGL, natural gas, renewable feedstocks and renewable fuels, and electric power markets, exposing our revenues, purchases, cost of operating activities and cash flows to fluctuations in the prices for these commodities. Generally, our policy is to remain exposed to the market prices of commodities; however, we use futures, forwards, swaps and options in various markets to balance physical systems, meet customer needs, manage price exposures on specific transactions, and do a limited amount of trading not directly related to our physical business, all of which may reduce our exposure to fluctuations in market prices. We also use the market knowledge gained from these activities to capture market opportunities such as moving physical commodities to more profitable locations, storing commodities to capture seasonal or time premiums, and blending commodities to capture quality upgrades.
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The following table indicates the consolidated balance sheet line items that include the fair values of commodity derivative assets and liabilities. The balances in the following table are presented on a gross basis, before the effects of counterparty and collateral netting. However, we have elected to present our commodity derivative assets and liabilities with the same counterparty on a net basis on our consolidated balance sheet when the legal right of offset exists.

| Millions of Dollars
| March 31, 2025 |  | December 31, 2024
| Commodity Derivatives | Effect of Collateral Netting | Net Carrying Value Presented on the Balance Sheet |  |  | Commodity Derivatives | Effect of Collateral Netting | Net Carrying Value Presented on the Balance Sheet
| Assets | Liabilities |  | Assets | Liabilities
Assets |  |  |  |  |  |  |  |  |  |
Prepaid expenses and other current assets | $ | 683 |  | (584) |  | — |  | 99 |  |  |  | 1,021 |  | (922) |  | — |  | 99 |
Liabilities |  |  |  |  |  |  |  |  |  |
Other accruals | 2,469 |  | (2,643) |  | 101 |  | (73) |  |  |  | 1,136 |  | (1,226) |  | 46 |  | (44) |
Other liabilities and deferred credits | 78 |  | (93) |  | 20 |  | 5 |  |  |  | 60 |  | (71) |  | 16 |  | 5 |
Total | $ | 3,230 |  | (3,320) |  | 121 |  | 31 |  |  |  | 2,217 |  | (2,219) |  | 62 |  | 60 |

At March 31, 2025, and December 31, 2024, there was no material cash collateral received or paid that was not offset on our consolidated balance sheet.
The realized and unrealized gains (losses) incurred from commodity derivatives, and the line items where they appear on our consolidated statement of income, were:

| Millions of Dollars
| Three Months Ended March 31 |  |
| 2025 |  |  | 2024 |  |  |  |
Sales and other operating revenues | $ | (65) |  |  | (202) |  |  |  |
Other income | 14 |  |  | 38 |  |  |  |
Purchased crude oil and products | (176) |  |  | (256) |  |  |  |
Net loss from commodity derivative activity | $ | (227) |  |  | (420) |  |  |  |

The following table summarizes our material net exposures resulting from outstanding commodity derivative contracts. These financial and physical derivative contracts are primarily used to manage price exposure on our underlying operations. The underlying exposures may be from nonderivative positions such as inventory volumes. Financial derivative contracts may also offset physical derivative contracts, such as forward purchase and sales contracts. The percentage of our derivative contract volumes expiring within the next 12 months was more than 90% at March 31, 2025, and December 31, 2024.
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| Open Position Long / (Short)
| March 31 2025 |  | December 31 2024
Commodity |  |  |
Crude oil, refined petroleum products, NGL and renewable feedstocks (millions of barrels) | (38) |  |  | (22) |
Natural gas (billions of cubic feet) | (8) |  |  | (14) |

Credit Risk from Derivative and Financial Instruments
Financial instruments potentially exposed to concentrations of credit risk consist primarily of trade receivables and derivative contracts.
Our trade receivables result primarily from the sale of products from, or related to, our refinery operations and reflect a broad national and international customer base, which limits our exposure to concentrations of credit risk. The majority of these receivables have payment terms of 30 days or less. We continually monitor this exposure and the creditworthiness of the counterparties and recognize bad debt expense based on a probability assessment of credit loss. Generally, we do not require collateral to limit the exposure to loss; however, we will sometimes use letters of credit, prepayments or master netting arrangements to mitigate credit risk with counterparties that both buy from and sell to us, as these agreements permit the amounts owed by us to others to be offset against amounts owed to us.
The credit risk from our derivative contracts, such as forwards and swaps, derives from the counterparty to the transaction. Individual counterparty exposure is managed within predetermined credit limits and includes the use of cash-call margins when appropriate, thereby reducing the risk of significant nonperformance. We also use futures, swaps and option contracts that have a negligible credit risk because these trades are cleared with an exchange clearinghouse and subject to mandatory margin requirements, typically on a daily basis, until settled.
Certain of our derivative instruments contain provisions that require us to post collateral if the derivative exposure exceeds a threshold amount. We have contracts with fixed threshold amounts and other contracts with variable threshold amounts that are contingent on our credit ratings. The variable threshold amounts typically decline for lower credit ratings, while both the variable and fixed threshold amounts typically revert to zero if our credit ratings fall below investment grade. Cash is the primary collateral in all contracts; however, many contracts also permit us to post letters of credit as collateral.
The aggregate fair values of all derivative instruments with such credit-risk-related contingent features that were in a liability position were immaterial at March 31, 2025, and December 31, 2024.
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Note 15—Fair Value Measurements
Recurring Fair Value Measurements
We carry certain assets and liabilities at fair value, which we measure at the reporting date using the price that would be received to sell an asset or paid to transfer a liability (i.e., an exit price), and disclose the quality of these fair values based on the valuation inputs used in these measurements under the following hierarchy:
•Level 1: Fair value measured with unadjusted quoted prices from an active market for identical assets or liabilities.
•Level 2: Fair value measured either with: (1) adjusted quoted prices from an active market for similar assets or liabilities; or (2) other valuation inputs that are directly or indirectly observable.
•Level 3: Fair value measured with unobservable inputs that are significant to the measurement.
We classify the fair value of an asset or liability based on the significance of its observable or unobservable inputs to the measurement. However, the fair value of an asset or liability initially reported as Level 3 will be subsequently reported as Level 2 if the unobservable inputs become inconsequential to its measurement or corroborating market data becomes available. Conversely, an asset or liability initially reported as Level 2 will be subsequently reported as Level 3 if corroborating market data becomes unavailable.
We used the following methods and assumptions to estimate the fair value of financial instruments:
•Cash and cash equivalents—The carrying amount reported on our consolidated balance sheet approximates fair value.
•Accounts and notes receivable—The carrying amount reported on our consolidated balance sheet approximates fair value.
•Derivative instruments—The fair value of our exchange-traded contracts is based on quoted market prices obtained from the New York Mercantile Exchange, the Intercontinental Exchange or other exchanges, and is reported as Level 1 in the fair value hierarchy. When exchange-cleared contracts lack sufficient liquidity, or are valued using either adjusted exchange-provided prices or nonexchange quotes, we classify those contracts as Level 2 or Level 3 based on the degree to which inputs are observable.
Physical commodity forward purchase and sales contracts and over-the-counter (OTC) financial swaps are generally valued using forward quotes provided by brokers and price index developers, such as Platts and Oil Price Information Service. We corroborate these quotes with market data and classify the resulting fair values as Level 2. When forward market prices are not available, we estimate fair value using the forward price of a similar commodity, adjusted for the difference in quality or location. In certain less liquid markets or for longer-term contracts, forward prices are not as readily available. In these circumstances, physical commodity purchase and sales contracts and OTC swaps are valued using internally developed methodologies that consider historical relationships among various commodities that result in management’s best estimate of fair value. We classify these contracts as Level 3. Physical and OTC commodity options are valued using industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and contractual prices for the underlying instruments, as well as other relevant economic measures. The degree to which these inputs are observable in the forward markets determines whether the options are classified as Level 2 or 3. We use a midmarket pricing convention (the midpoint between bid and ask prices). When appropriate, valuations are adjusted to reflect credit considerations, generally based on available market evidence.
When applicable, we determine the fair value of interest rate swaps based on observable market valuations for interest rate swaps that have notional amounts, terms and pay and reset frequencies similar to ours.
When applicable, we determine the fair value of foreign currency derivatives based on observable market data and classify the resulting fair values as Level 2.
•Rabbi trust assets—These deferred compensation investments are measured at fair value using unadjusted quoted prices available from national securities exchanges and are therefore categorized as Level 1 in the fair value hierarchy.
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•Investment in NOVONIX Limited (NOVONIX)—Our investment in NOVONIX is measured at fair value using unadjusted quoted prices available from the Australian Securities Exchange and is therefore categorized as Level 1 in the fair value hierarchy.
•Other investments—Includes other marketable securities with observable market prices.
•Debt—The carrying amount of our floating-rate debt approximates fair value. The fair value of our fixed-rate debt is estimated primarily based on observable market prices.
The following tables display the fair value hierarchy for our financial assets and liabilities either accounted for or disclosed at fair value on a recurring basis. These values are determined by treating each contract as the fundamental unit of account; therefore, derivative assets and liabilities with the same counterparty are shown on a gross basis in the hierarchy sections of these tables, before the effects of counterparty and collateral netting. The following tables also reflect the effect of netting derivative assets and liabilities with the same counterparty for which we have the legal right of offset and collateral netting.
The carrying values and fair values by hierarchy of our financial assets and liabilities, either carried or disclosed at fair value, including any effects of counterparty and collateral netting, were:

| Millions of Dollars
| March 31, 2025
| Fair Value Hierarchy |  | Total Fair Value of Gross Assets & Liabilities | Effect of Counterparty Netting | Effect of Collateral Netting | Difference in Carrying Value and Fair Value | Net Carrying Value Presented on the Balance Sheet |
| Level 1 |  | Level 2 |  | Level 3
Commodity Derivative Assets |  |  |  |  |  |  |  |  |  |  |  |
Exchange-cleared instruments | $ | 3,141 |  |  | — |  |  | — |  |  | 3,141 |  | (3,126) |  | — |  | — |  | 15 |  |
Physical forward contracts | — |  |  | 85 |  |  | 4 |  |  | 89 |  | (5) |  | — |  | — |  | 84 |  |
Rabbi trust assets | 143 |  |  | — |  |  | — |  |  | 143 |  | N/A | N/A | — |  | 143 |  |
Investment in NOVONIX | 26 |  |  | — |  |  | — |  |  | 26 |  | N/A | N/A | — |  | 26 |  |
| $ | 3,310 |  |  | 85 |  |  | 4 |  |  | 3,399 |  | (3,131) |  | — |  | — |  | 268 |  |
Commodity Derivative Liabilities |  |  |  |  |  |  |  |  |  |  |  |
Exchange-cleared instruments | $ | 3,247 |  |  | — |  |  | — |  |  | 3,247 |  | (3,126) |  | (121) |  | — |  | — |  |
Physical forward contracts | — |  |  | 72 |  |  | 1 |  |  | 73 |  | (5) |  | — |  | — |  | 68 |  |
Floating-rate debt | — |  |  | 550 |  |  | — |  |  | 550 |  | N/A | N/A | — |  | 550 |  |
Fixed-rate debt, excluding finance leases and software obligations | — |  |  | 16,990 |  |  | — |  |  | 16,990 |  | N/A | N/A | 890 |  | 17,880 |  |
| $ | 3,247 |  |  | 17,612 |  |  | 1 |  |  | 20,860 |  | (3,131) |  | (121) |  | 890 |  | 18,498 |  |

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| Millions of Dollars
| December 31, 2024
| Fair Value Hierarchy |  | Total Fair Value of Gross Assets & Liabilities | Effect of Counterparty Netting | Effect of Collateral Netting | Difference in Carrying Value and Fair Value | Net Carrying Value Presented on the Balance Sheet |
| Level 1 |  | Level 2 |  | Level 3 |
Commodity Derivative Assets |  |  |  |  |  |  |  |  |  |  |  |
Exchange-cleared instruments | $ | 2,137 |  |  | — |  |  | — |  |  | 2,137 |  | (2,111) |  | — |  | — |  | 26 |  |
OTC instruments | — |  |  | 7 |  |  | — |  |  | 7 |  | — |  | — |  | — |  | 7 |  |
Physical forward contracts | — |  |  | 70 |  |  | 3 |  |  | 73 |  | (7) |  | — |  | — |  | 66 |  |
Rabbi trust assets | 153 |  |  | — |  |  | — |  |  | 153 |  | N/A | N/A | — |  | 153 |  |
Investment in NOVONIX | 36 |  |  | — |  |  | — |  |  | 36 |  | N/A | N/A | — |  | 36 |  |
Foreign currency derivative | — |  |  | 67 |  |  | — |  |  | 67 |  | N/A | N/A | — |  | 67 |  |
| $ | 2,326 |  |  | 144 |  |  | 3 |  |  | 2,473 |  | (2,118) |  | — |  | — |  | 355 |  |
Commodity Derivative Liabilities |  |  |  |  |  |  |  |  |  |  |  |
Exchange-cleared instruments | $ | 2,173 |  |  | — |  |  | — |  |  | 2,173 |  | (2,111) |  | (62) |  | — |  | — |  |
Physical forward contracts | — |  |  | 45 |  |  | 1 |  |  | 46 |  | (7) |  | — |  | — |  | 39 |  |
Floating-rate debt | — |  |  | 1,760 |  |  | — |  |  | 1,760 |  | N/A | N/A | — |  | 1,760 |  |
Fixed-rate debt, excluding finance leases and software obligations | — |  |  | 16,913 |  |  | — |  |  | 16,913 |  | N/A | N/A | 1,020 |  | 17,933 |  |
| $ | 2,173 |  |  | 18,718 |  |  | 1 |  |  | 20,892 |  | (2,118) |  | (62) |  | 1,020 |  | 19,732 |  |

The rabbi trust assets and investment in NOVONIX are recorded in the “Investments and long-term receivables” line item, and floating-rate and fixed-rate debt are recorded in the “Short-term debt” and “Long-term debt” line items on our consolidated balance sheet. The foreign currency derivative was recorded in the “Prepaid expenses and other current assets” line item on our consolidated balance sheet at December 31, 2024. See Note 14—Derivatives and Financial Instruments, for information regarding where the assets and liabilities related to our commodity derivatives are recorded on our consolidated balance sheet.
Nonrecurring Fair Value Measurements
PP&E
In the first quarter of 2024, we remeasured the carrying value of the net PP&E of certain crude oil processing and logistics assets in California to fair value. Fair value was determined using a market approach. These valuations resulted in Level 3 nonrecurring fair value measurements.
See Note 9—Impairments, for additional information regarding before-tax impairments recorded in 2024.
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Note 16—Pension and Postretirement Plans
The components of net periodic benefit cost for the three months ended March 31, 2025 and 2024, were as follows:

| Millions of Dollars
| Pension Benefits |  | Other Benefits
| 2025 |  | 2024 |  | 2025 |  |  | 2024 |
| U.S. |  | Int’l. |  | U.S. |  | Int’l. |  |  |  |
Components of Net Periodic Benefit Cost |  |  |  |  |  |  |  |  |  |  |
Three Months Ended March 31 |  |  |  |  |  |  |  |  |  |  |
Service cost | $ | 31 |  |  | 3 |  |  | 29 |  |  | 3 |  |  | — |  |  | 1 |
Interest cost | 32 |  |  | 8 |  |  | 28 |  |  | 8 |  |  | 2 |  |  | 2 |
Expected return on plan assets | (38) |  |  | (11) |  |  | (38) |  |  | (11) |  |  | — |  |  | — |
Amortization of net actuarial loss (gain) | 4 |  |  | — |  |  | 3 |  |  | — |  |  | (1) |  |  | (1) |
Settlements | 2 |  |  | — |  |  | 1 |  |  | — |  |  | — |  |  | — |
Net periodic benefit cost* | $ | 31 |  |  | — |  |  | 23 |  |  | — |  |  | 1 |  |  | 2 |
* Included in the “Operating expenses” and “Selling, general and administrative expenses” line items on our consolidated statement of income.

During the three months ended March 31, 2025, we contributed $49 million to our U.S. pension and other postretirement benefit plans and $1 million to our international pension plans. We currently expect to make additional contributions of approximately $26 million to our U.S. pension and other postretirement benefit plans and approximately $4 million to our international pension plans during the remainder of 2025. Cash contributions are included in the “Other” line item of the “Cash Flows From Operating Activities” section of our consolidated statement of cash flows.
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Note 17—Accumulated Other Comprehensive Loss
Changes in the balances of each component of accumulated other comprehensive loss were as follows:

| Millions of Dollars
| Defined Benefit Plans |  | Foreign Currency Translation |  | Hedging |  | Accumulated Other Comprehensive Loss
December 31, 2024 | $ | (140) |  |  | (262) |  |  | (5) |  |  | (407) |
Other comprehensive income before reclassifications | 2 |  |  | 100 |  |  | — |  |  | 102 |
Amounts reclassified from accumulated other comprehensive loss |  |  |  |  |  |  |
Defined benefit plans* |  |  |  |  |  |  |
Amortization of net actuarial loss and settlements | 4 |  |  | — |  |  | — |  |  | 4 |
Foreign currency translation** | — |  |  | (12) |  |  | — |  |  | (12) |
Hedging | — |  |  | — |  |  | — |  |  | — |
Net current period other comprehensive income | 6 |  |  | 88 |  |  | — |  |  | 94 |
March 31, 2025 | $ | (134) |  |  | (174) |  |  | (5) |  |  | (313) |
December 31, 2023 | $ | (120) |  |  | (157) |  |  | (5) |  |  | (282) |
Other comprehensive income (loss) before reclassifications | 1 |  |  | (32) |  |  | — |  |  | (31) |
Amounts reclassified from accumulated other comprehensive loss |  |  |  |  |  |  |
Defined benefit plans* |  |  |  |  |  |  |
Amortization of net actuarial loss and settlements | 1 |  |  | — |  |  | — |  |  | 1 |
Foreign currency translation | — |  |  | — |  |  | — |  |  | — |
Hedging | — |  |  | — |  |  | — |  |  | — |
Net current period other comprehensive income (loss) | 2 |  |  | (32) |  |  | — |  |  | (30) |
March 31, 2024 | $ | (118) |  |  | (189) |  |  | (5) |  |  | (312) |
* Included in the computation of net periodic benefit cost. See Note 16—Pension and Postretirement Plans, for additional information.
** Included in the gain on sale of Coop, recognized in the “Net gain on dispositions” line item on our consolidated statement of income. See Note 7—Investments, Loans and Long-Term Receivables, for additional information.

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Note 18—Related Party Transactions
Significant transactions with related parties were:

| Millions of Dollars
| Three Months Ended March 31 |  |
| 2025 |  |  | 2024 |  |  |  |
Operating revenues and other income (a) | $ | 1,036 |  |  | 1,133 |  |  |  |
Purchases (b) | 4,010 |  |  | 5,231 |  |  |  |
Operating expenses and selling, general and administrative expenses (c) | 74 |  |  | 69 |  |  |  |

(a)We sold NGL, other petrochemical feedstocks and solvents to Chevron Phillips Chemical Company LLC (CPChem), gas oil and hydrogen feedstocks to Excel Paralubes LLC (Excel Paralubes), and refined petroleum products to several of our equity affiliates in the M&S segment, including OnCue and CF United LLC (CF United). We also sold certain feedstocks and intermediate products to WRB Refining LP (WRB) and acted as an agent for WRB in supplying crude oil and other feedstocks for a fee. In addition, we charged several of our equity affiliates, including CPChem, for the use of common facilities, such as steam generators, waste and water treaters and warehouse facilities.
(b)We purchased crude oil, refined petroleum products, NGL and solvents from WRB. We also purchased natural gas and NGL from CPChem, as well as other feedstocks from various equity affiliates, for use in our refinery and fractionation processes. In addition, we purchased base oils and fuel products from Excel Paralubes for use in our specialty and refining businesses. We paid NGL fractionation fees to CPChem. We also paid fees to various pipeline equity affiliates for transporting crude oil, refined petroleum products and NGL.
(c)We paid consignment fees to CF United, and utility and processing fees to various equity affiliates.
Note 19—Segment Disclosures and Related Information
Effective April 1, 2024, we changed the internal financial information reviewed by our chief executive officer to evaluate performance and allocate resources to our operating segments. This resulted in changes to the composition of our operating segments, as well as measurement changes for certain activities between our operating segments. The primary effects are summarized below. Prior period information has been recast for comparability.
•Establishment of a Renewable Fuels operating segment, which includes renewable fuels activities and assets historically reported in our Refining, M&S and Midstream operating segments.
•Change in method of allocating results for certain Gulf Coast distillate export activities from our M&S operating segment to our Refining operating segment.
•Reclassification of certain crude oil and international clean products trading activities between our M&S operating segment and our Refining operating segment.
•Change in reporting of our investment in NOVONIX from our Midstream operating segment to Corporate and Other.
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Our operating segments are:
1)Midstream—Provides crude oil and refined petroleum product transportation, terminaling and processing services, as well as natural gas and NGL transportation, storage, fractionation, gathering, processing and marketing services in the United States. In addition, this segment exports liquefied petroleum gas to global markets.
2)Chemicals—Consists of our 50% equity investment in CPChem, which manufactures and markets petrochemicals and plastics on a worldwide basis.
3)Refining—Refines crude oil and other feedstocks into petroleum products, such as gasoline and distillates, including aviation fuels. This segment includes 11 refineries in the United States and Europe.
4)Marketing and Specialties—Purchases for resale and markets refined products, mainly in the United States and Europe. In addition, this segment includes the manufacturing and marketing of base oils and lubricants.
5)Renewable Fuels—Processes renewable feedstocks into renewable products at the Rodeo Complex and at our Humber Refinery. In addition, this segment includes the global activities to procure renewable feedstocks, manage certain regulatory credits, and market renewable fuels.
Corporate and Other includes general corporate overhead, interest income, interest expense, our investment in research of new technologies, our investment in NOVONIX, and various other corporate activities. Corporate assets include all cash, cash equivalents, income tax-related assets and enterprise information technology assets.
Intersegment sales are at prices that we believe approximate market.
Through our implementation of ASU No. 2023-07, “Segment Reporting (Topic 280)—Improvements to Reportable Segment Disclosures,” we are including additional disclosures regarding significant segment expenses regularly provided to our chief operating decision maker (CODM), who is our Chief Executive Officer. The measure of segment profit or loss reviewed by our CODM is “income (loss) before income taxes.” The CODM uses segment income (loss) before income taxes to allocate resources to each segment predominantly in the annual budgeting and forecasting process. The CODM compares budget-to-actual segment income (loss) before income taxes on a monthly and quarterly basis and considers trend analyses as well as other market factors when making decisions about allocating capital and personnel to the segments. The measure of segment assets reported on our consolidated balance sheet reviewed by our CODM is “Total Assets.”
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Analysis of Results by Operating Segment

| Millions of Dollars
| Three Months Ended March 31, 2025
| Operating Segments |  |  |
| Midstream | Chemicals | Refining | M&S | Renewable Fuels | Corporate and Other | Consolidating Adjustments | Total Consolidated
Revenues and Other Income |  |  |  |  |  |  |  |
Third-party sales and other operating revenues | $ | 4,827 |  | — |  | 5,702 |  | 19,163 |  | 728 |  | 10 |  | — |  | 30,430 |
Intercompany revenues | 631 |  | — |  | 10,173 |  | 478 |  | 781 |  | 2 |  | (12,065) |  | — |
Total sales and other operating revenues | 5,458 |  | — |  | 15,875 |  | 19,641 |  | 1,509 |  | 12 |  | (12,065) |  | 30,430 |
Equity in earnings of affiliates | 110 |  | 113 |  | (105) |  | 36 |  | (1) |  | — |  | — |  | 153 |
Net gain on dispositions | 69 |  | — |  | — |  | 1,018 |  | — |  | — |  | — |  | 1,087 |
Other income | 10 |  | — |  | 3 |  | 6 |  | 19 |  | 18 |  | — |  | 56 |
Total Revenues and Other Income | 5,647 |  | 113 |  | 15,773 |  | 20,701 |  | 1,527 |  | 30 |  | (12,065) |  | 31,726 |
Costs and Expenses |  |  |  |  |  |  |  |
Purchased crude oil and products | 4,089 |  | — |  | 15,025 |  | 19,045 |  | 1,536 |  | — |  | (12,035) |  | 27,660 |
Operating expenses* | 458 |  | 2 |  | 1,074 |  | 18 |  | 96 |  | 4 |  | (30) |  | 1,622 |
Selling, general and administrative expenses* | 53 |  | (2) |  | 46 |  | 328 |  | 18 |  | 76 |  | — |  | 519 |
Depreciation and amortization | 233 |  | — |  | 456 |  | 20 |  | 23 |  | 59 |  | — |  | 791 |
Impairments | — |  | — |  | 1 |  | — |  | — |  | 25 |  | — |  | 26 |
Taxes other than income taxes | 61 |  | — |  | 110 |  | 9 |  | 35 |  | 18 |  | — |  | 233 |
Interest and debt expense | — |  | — |  | — |  | — |  | — |  | 221 |  | — |  | 221 |
Other segment items** | 2 |  | — |  | (2) |  | (1) |  | 4 |  | 3 |  | — |  | 6 |
Total Costs and Expenses | 4,896 |  | — |  | 16,710 |  | 19,419 |  | 1,712 |  | 406 |  | (12,065) |  | 31,078 |
Income (loss) before income taxes | $ | 751 |  | 113 |  | (937) |  | 1,282 |  | (185) |  | (376) |  | — |  | 648 |
* These significant expense categories and amounts align with the segment-level information that is regularly provided to the CODM. The total of the line items "Operating expenses" and "Selling, general and administrative expenses" is considered "Controllable costs" and is provided to the CODM.
** “Other segment items” for each reportable segment includes the following line items on our consolidated statement of income: “Accretion on discounted liabilities” and “Foreign currency transaction (gains) losses.”

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| Millions of Dollars
| Three Months Ended March 31, 2024
| Operating Segments |  |  |
| Midstream | Chemicals | Refining | M&S | Renewable Fuels | Corporate and Other | Consolidating Adjustments | Total Consolidated
Revenues and Other Income |  |  |  |  |  |  |  |
Third-party sales and other operating revenues | $ | 4,124 |  | — |  | 9,225 |  | 22,084 |  | 368 |  | 10 |  | — |  | 35,811 |
Intercompany revenues | 717 |  | — |  | 12,684 |  | 518 |  | 775 |  | 3 |  | (14,697) |  | — |
Total sales and other operating revenues | 4,841 |  | — |  | 21,909 |  | 22,602 |  | 1,143 |  | 13 |  | (14,697) |  | 35,811 |
Equity in earnings of affiliates | 155 |  | 201 |  | 108 |  | 64 |  | — |  | — |  | — |  | 528 |
Net gain on dispositions | — |  | — |  | — |  | — |  | — |  | — |  | — |  | — |
Other income | 4 |  | — |  | 33 |  | 9 |  | 5 |  | 56 |  | (10) |  | 97 |
Total Revenues and Other Income | 5,000 |  | 201 |  | 22,050 |  | 22,675 |  | 1,148 |  | 69 |  | (14,707) |  | 36,436 |
Costs and Expenses |  |  |  |  |  |  |  |
Purchased crude oil and products | 3,600 |  | — |  | 20,405 |  | 21,915 |  | 1,149 |  | — |  | (14,683) |  | 32,386 |
Operating expenses* | 434 |  | (2) |  | 953 |  | 16 |  | 72 |  | 3 |  | (24) |  | 1,452 |
Selling, general and administrative expenses* | 76 |  | (2) |  | 38 |  | 319 |  | 11 |  | 115 |  | — |  | 557 |
Depreciation and amortization | 229 |  | — |  | 208 |  | 36 |  | 6 |  | 25 |  | — |  | 504 |
Impairments | 59 |  | — |  | 105 |  | — |  | — |  | 1 |  | — |  | 165 |
Taxes other than income taxes | 44 |  | — |  | 121 |  | 15 |  | (34) |  | 19 |  | — |  | 165 |
Interest and debt expense | — |  | — |  | — |  | — |  | — |  | 227 |  | — |  | 227 |
Other segment items** | 4 |  | — |  | 4 |  | 8 |  | (1) |  | 1 |  | — |  | 16 |
Total Costs and Expenses | 4,446 |  | (4) |  | 21,834 |  | 22,309 |  | 1,203 |  | 391 |  | (14,707) |  | 35,472 |
Income (loss) before income taxes | $ | 554 |  | 205 |  | 216 |  | 366 |  | (55) |  | (322) |  | — |  | 964 |
* These significant expense categories and amounts align with the segment-level information that is regularly provided to the CODM. The total of the line items "Operating expenses" and "Selling, general and administrative expenses" is considered "Controllable costs" and is provided to the CODM.
** “Other segment items” for each reportable segment includes the following line items on our consolidated statement of income: “Accretion on discounted liabilities” and “Foreign currency transaction (gains) losses.”

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Other Segment Disclosures

| Millions of Dollars |
| Operating Segments |  |  |
| Midstream | Chemicals | Refining | M&S | Renewable Fuels | Corporate and Other | Total Consolidated |
Three Months Ended March 31, 2025 |
Interest Income | $ | — |  | — |  | — |  | — |  | — |  | 34 |  | 34 |  |
Capital Expenditures and Investments | 216 |  | — |  | 176 |  | 15 |  | 9 |  | 7 |  | 423 |  |
Three Months Ended March 31, 2024 |
Interest Income | $ | — |  | — |  | — |  | — |  | — |  | 42 |  | 42 |  |
Capital Expenditures and Investments | 255 |  | — |  | 135 |  | 15 |  | 217 |  | 6 |  | 628 |  |

| Millions of Dollars |
| Operating Segments |  |  |
| Midstream | Chemicals | Refining | M&S | Renewable Fuels | Corporate and Other | Total Consolidated |
As of March 31, 2025 |
Investments In and Advances to Affiliates | $ | 2,261 |  | 7,899 |  | 2,278 |  | 557 |  | 15 |  | 2 |  | 13,012 |  |
Total Assets | 27,421 |  | 7,921 |  | 19,732 |  | 10,382 |  | 3,144 |  | 3,238 |  | 71,838 |  |
As of December 31, 2024 |
Investments In and Advances to Affiliates | $ | 3,080 |  | 7,819 |  | $ | 2,381 |  | 719 |  | 16 |  | 2 |  | 14,017 |  |
Total Assets | 28,334 |  | 7,842 |  | 19,599 |  | 9,799 |  | 3,142 |  | 3,866 |  | 72,582 |  |

Note 20—Income Taxes
Our effective income tax rate for the three months ended March 31, 2025, was 19%, compared to 21% for the corresponding period of 2024. The decrease in our effective rate for the three months ended March 31, 2025, was primarily attributable to the effects of state income taxes in the period.
The effective tax rate for the three months ended March 31, 2025, varied from the U.S. federal statutory income tax rate primarily due to the impact of tax benefits from share-based compensation plans and non-taxable items.
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Note 21—DCP Midstream Class A Segment
DCP Midstream Class A Segment is comprised of the businesses, activities, assets and liabilities of DCP LP, its subsidiaries and its general partner entities. DCP LP is a master limited partnership whose operations currently include producing and fractionating NGL; gathering, compressing, treating and processing natural gas; recovering condensate; and transporting, trading, marketing and storing natural gas and NGL. DCP Midstream Class A Segment is a consolidated VIE as we are the primary beneficiary.
The most significant assets of DCP Midstream Class A Segment that are available to settle only its obligations, along with its most significant liabilities for which its creditors do not have recourse to Phillips 66’s general credit, were:

| Millions of Dollars
| March 31 2025 |  | December 31 2024
Accounts receivable | $ | 654 |  |  | 638 |
Net properties, plants and equipment | 8,871 |  |  | 8,861 |
Investments and long-term receivables | 811 |  |  | 1,622 |
Accounts payable | 866 |  |  | 909 |
Short-term debt | 529 |  |  | 532 |
Long-term debt | 2,908 |  |  | 2,913 |

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Item 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Unless otherwise indicated, the “company,” “we,” “our,” “us” and “Phillips 66” are used in this report to refer to the businesses of Phillips 66 and its consolidated subsidiaries.
Management’s Discussion and Analysis is the company’s analysis of its financial performance, financial condition, and significant trends that may affect future performance. It should be read in conjunction with the consolidated financial statements and notes included elsewhere in this report. It contains forward-looking statements including, without limitation, statements relating to the company’s plans, strategies, objectives, expectations and intentions that are made pursuant to the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995. The words “anticipate,” “estimate,” “believe,” “budget,” “continue,” “could,” “intend,” “may,” “plan,” “potential,” “predict,” “seek,” “should,” “will,” “would,” “expect,” “objective,” “projection,” “forecast,” “goal,” “guidance,” “outlook,” “effort,” “target,” “priorities” and similar expressions often identify forward-looking statements, but the absence of these words does not mean a statement is not forward-looking. The forward-looking statements made in this Quarterly Report on Form 10-Q are based on events or circumstances as of the date on which the statements are made. The company does not undertake to update, revise or correct any of the forward-looking information included in this Quarterly Report on Form 10-Q to reflect events or circumstances after the date of this Quarterly Report on Form 10-Q or to reflect new information or the occurrence of unanticipated events unless required to do so pursuant to applicable law. Readers are cautioned that such forward-looking statements should be read in conjunction with the company’s disclosures under the heading: “CAUTIONARY STATEMENT FOR THE PURPOSES OF THE ‘SAFE HARBOR’ PROVISIONS OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995.”
The term “earnings” as used in Management’s Discussion and Analysis refers to net income attributable to Phillips 66. The terms “results,” “before-tax income” or “before-tax loss” as used in Management’s Discussion and Analysis refer to income (loss) before income taxes.
EXECUTIVE OVERVIEW AND BUSINESS ENVIRONMENT
Phillips 66 is uniquely positioned as a leading integrated downstream energy provider operating with Midstream, Chemicals, Refining, Marketing and Specialties (M&S), and Renewable Fuels segments. At March 31, 2025, we had total assets of $71.8 billion. Our common stock trades on the New York Stock Exchange under the symbol PSX.
Executive Overview
In the first quarter of 2025, we reported earnings of $487 million and cash provided by operating activities of $187 million. During the quarter, we funded capital expenditures and investments of $423 million and received proceeds from asset dispositions of $2 billion. Additionally, we repaid $1.3 billion of debt, paid $247 million to repurchase shares of our common stock and paid $469 million of dividends to our common stockholders. We ended the first quarter of 2025 with $1.5 billion of cash and cash equivalents and $5.4 billion of total committed capacity available under our credit facilities.
Strategic Priorities Update
In January 2025, we announced the next phase of priorities along with financial and operational initiatives through year-end 2027. With these targets, the company is continuing to focus on creating shareholder value; driving disciplined growth and returns; and maintaining financial strength and flexibility. We are focused on operational and cost reduction targets intended to drive world-class operations across our portfolio, while maintaining emphasis on growing our Midstream and Chemicals businesses.
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•Shareholder Returns – We believe shareholder value is enhanced through, among other things, a secure, competitive and growing dividend, complemented by share repurchases. Our financial target aims to return greater than 50% of net cash provided by operating activities to shareholders through share repurchases and dividends. The amount and timing of future dividend payments and the level and timing of future share repurchases is subject to the discretion of, and approval by, our Board of Directors and will depend on various factors including our share price, results of operations, financial condition and cash required for future business plans.
•In April 2025, our Board of Directors declared a quarterly cash dividend of $1.20 per common share, representing a $0.05 increase, reflecting our commitment to a secure, competitive and growing dividend.
•World-Class Operations – We are focused on achieving operational excellence by optimizing utilization rates and product yield at our refineries through reliable and safe operations, which will enable us to capture the value available in the market in terms of prices and margins. With our new targets, we remain focused on a competitive cost structure and plan to enhance Refining segment returns and increase our utilization rates by focusing on low-capital, higher-return projects that increase asset reliability and improve market capture.
•We continue to focus on Refining performance, targeting an annual clean product yield of greater than 86%, crude oil capacity utilization rates higher than industry average, and continuing to improve our competitive cost structure.
•Disciplined Growth and Returns – A disciplined capital allocation process ensures we invest in projects that are expected to generate competitive returns. Our strategy remains focused on growing our Midstream and Chemicals businesses. Within our Midstream segment, we are primarily focused on maximizing the value of our fully integrated natural gas liquids (NGL) wellhead-to-market value chain.
•In January 2025, we closed on the sale of our 49% ownership in Coop Mineraloel AG (Coop) and DCP Midstream, LP’s (DCP LP) 25% ownership in Gulf Coast Express Pipeline LLC (GCX) and received total proceeds of $2 billion. We will continue to evaluate future opportunities to rationalize our asset portfolio. We have budgeted $2.1 billion for 2025 capital expenditures and investments, exclusive of acquisitions, which includes $1.1 billion of growth capital, primarily in our Midstream segment. Refer to Note 7—Investments, Loans and Long-Term Receivables, in the Notes to Consolidated Financial Statements for additional information on the investment dispositions.
•We continued expansion of our Midstream NGL wellhead-to-market platform with a recent acquisition. On April 1, 2025, we acquired all issued and outstanding equity interests in each of EPIC Y-Grade GP, LLC and EPIC Y-Grade, LP, together with their respective subsidiaries, which own various long haul natural gas liquids pipelines, fractionation facilities and distribution systems. Refer to Note 3—Business Combinations, in the Notes to Consolidated Financial Statements for additional information.
•Our new financial targets through 2027 reflect our plans to grow our Midstream and Chemicals businesses, as well as maintain total annual capital expenditures and investments of approximately $2 billion, excluding acquisitions.
•Financial Strength and Flexibility – We use a variety of funding sources to support our liquidity requirements, including cash from operations, debt and proceeds from dispositions. Our focus remains on protecting the stable cash generation from the Midstream and Marketing and Specialties (M&S) businesses while balancing continued portfolio optimization.
•We are targeting reductions of total debt to $17 billion and to lower our debt to capital ratio.
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Basis of Presentation
Effective April 1, 2024, we changed the internal financial information reviewed by our chief executive officer to evaluate performance and allocate resources to our operating segments. This resulted in changes to the composition of our operating segments, as well as measurement changes for certain activities between our operating segments. The primary effects are summarized below. Prior period information has been recast for comparability.
•Establishment of a Renewable Fuels operating segment, which includes renewable fuels activities and assets historically reported in our Refining, M&S and Midstream operating segments.
•Change in method of allocating results for certain Gulf Coast distillate export activities from our M&S operating segment to our Refining operating segment.
•Reclassification of certain crude oil and international clean products trading activities between our M&S operating segment and our Refining operating segment.
•Change in reporting of our investment in NOVONIX Limited (NOVONIX) from our Midstream operating segment to Corporate and Other.
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Business Environment
Our Midstream segment includes our Transportation and natural gas liquids (NGL) businesses. Our Transportation business contains fee-based operations not directly exposed to commodity price risk. Our NGL business, including DCP Midstream Class A Segment, DCP Sand Hills Pipeline, LLC (DCP Sand Hills) and DCP Southern Hills Pipeline, LLC (DCP Southern Hills), contains both fee-based operations and operations directly impacted by NGL and natural gas prices. The weighted-average NGL price was $0.74 per gallon during the first quarter of 2025, compared with $0.70 per gallon during the first quarter of 2024. The Henry Hub natural gas price was $4.27 per million British thermal units (MMBtu) during the first quarter of 2025, compared with $2.41 per MMBtu during the first quarter of 2024. The increases in NGL and natural gas prices were primarily due to colder weather and an increase in liquefied natural gas exports.
Our Chemicals segment consists of our 50% equity investment in Chevron Phillips Chemical Company LLC (CPChem). The chemicals and plastics industry is mainly a commodity-based industry where the margins for key products are based on supply and demand, as well as cost factors. The benchmark high-density polyethylene chain margin was 10.9 cents per pound in the first quarter of 2025, compared with 16.4 cents per pound in the first quarter of 2024. The decrease was mainly due to higher natural gas and ethane prices and lower polyethylene demand.
Our Refining segment results are driven by several factors, including market crack spreads, refinery throughput, feedstock costs, product yields, turnaround activity, and other operating costs. Market crack spreads are used as indicators of refining margins and measure the difference between market prices for refined petroleum products and crude oil. The composite 3:2:1 market crack spread for our business decreased to an average of $15.83 per barrel during the first quarter of 2025, from an average of $19.45 per barrel during the first quarter of 2024. The decrease in the composite market crack spread was primarily driven by market instability as geopolitical events drove demand concerns. The price of U.S. benchmark crude oil, West Texas Intermediate (WTI) at Cushing, Oklahoma, decreased to an average of $71.46 per barrel during the first quarter of 2025, from an average of $77.07 per barrel during the first quarter of 2024, primarily due to increased supply.
Results for our M&S segment depend largely on marketing fuel and lubricant margins and sales volumes of our refined products. While marketing fuel and lubricant margins are primarily driven by market factors, largely determined by the relationship between supply and demand, marketing fuel margins, in particular, are influenced by trends in spot prices, and where applicable, retail prices for refined products in the regions and countries where we operate.
Our Renewable Fuels segment consists of the operations and assets of the Rodeo Renewable Energy Complex (Rodeo Complex), as well as the global activities to procure renewable feedstocks, manage certain regulatory credits, and market renewable fuels. Results for our Renewable Fuels segment are impacted by several factors, including the market price of renewable fuels, feedstock costs, throughput, operating costs and the value of certain regulatory credits, as well as other market factors, largely determined by the relationship between supply and demand.
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RESULTS OF OPERATIONS
Unless otherwise indicated, discussion of results for the three months ended March 31, 2025, is based on a comparison with the corresponding period of 2024.
Consolidated Results
A summary of income (loss) before income taxes by business segment with a reconciliation to net income attributable to Phillips 66 follows:

| Millions of Dollars
| Three Months Ended March 31 |  |
| 2025 |  |  | 2024 |  |  |  |
Midstream | $ | 751 |  |  | 554 |  |  |  |
Chemicals | 113 |  |  | 205 |  |  |  |
Refining | (937) |  |  | 216 |  |  |  |
Marketing and Specialties | 1,282 |  |  | 366 |  |  |  |
Renewable Fuels | (185) |  |  | (55) |  |  |  |
Corporate and Other | (376) |  |  | (322) |  |  |  |
Income before income taxes | 648 |  |  | 964 |  |  |  |
Income tax expense | 122 |  |  | 203 |  |  |  |
Net income | 526 |  |  | 761 |  |  |  |
Less: net income attributable to noncontrolling interests | 39 |  |  | 13 |  |  |  |
Net income attributable to Phillips 66 | $ | 487 |  |  | 748 |  |  |  |

Our net income attributable to Phillips 66 in the first quarter of 2025 was $487 million, compared with $748 million in the first quarter of 2024. The decrease was primarily due to a decline in realized refining margins primarily driven by lower market crack spreads, as well as lower volumes and higher costs driven by planned turnaround activity. The decrease was also attributable to lower equity earnings from CPChem and declining domestic marketing fuel margins. These decreases were partially offset by a before-tax gain of $1 billion associated with the sale of our investment in Coop recognized in our M&S segment.
See the “Segment Results” section for additional information on our segment results.
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Statement of Income Analysis
Sales and other operating revenues and purchased crude oil and products decreased 15% for the three months ended March 31, 2025. The decreases in both line items were due to lower prices for refined petroleum products and crude oil, partially offset by an increase in prices for NGL, as well as lower volumes primarily attributable to turnaround activity.
Equity in earnings of affiliates decreased 71% for the three months ended March 31, 2025. The decrease was primarily attributable to lower equity earnings from WRB Refining LP (WRB) resulting from lower margins, as well as lower equity earnings from CPChem. See the Chemicals segment analysis in the “Segment Results” section for additional information regarding CPChem.
Net gain on dispositions increased $1,087 million for the three months ended March 31, 2025, primarily due to a before-tax gain of $1 billion associated with the sale of our investment in Coop recognized in the M&S segment. Refer to Note 7—Investments, Loans and Long-Term Receivables, in the Notes to Consolidated Financial Statements for additional information regarding the sale of Coop.
Other income decreased 42% for the three months ended March 31, 2025, primarily due to lower results from trading activities, as well as a decrease in the fair value of our investment in NOVONIX. These decreases were partially offset by Clean Fuel Production credits recorded in the first quarter of 2025.
Operating expenses increased 12% for the three months ended March 31, 2025. The increase was primarily due to higher turnaround and utility costs.
Depreciation and amortization increased 57% for the three months ended March 31, 2025, primarily due to $246 million of accelerated depreciation recorded in the first quarter of 2025 associated with our plan to cease operations at our Los Angeles Refinery in the fourth quarter of 2025. See Note 2—Restructuring, in the Notes to Consolidated Financial Statements for information regarding our plans to cease operations at our Los Angeles Refinery.
Impairments decreased 84% for the three months ended March 31, 2025. The decrease for the three months ended March 31, 2025, was primarily due to before-tax impairments of $163 million recorded in our Refining and Midstream segments in the first quarter of 2024 related to certain crude oil processing and logistics assets in California. See Note 9—Impairments, in the Notes to Consolidated Financial Statements for additional information regarding impairments.
Taxes other than income taxes increased 41% for the three months ended March 31, 2025. The increase was primarily driven by the expiration of the Biodiesel Blender Tax Credit, as well as an increase in taxes related to feedstock imports at the Rodeo Complex.
Income tax expense decreased 40% for the three months ended March 31, 2025, primarily due to lower income before income taxes. See Note 20—Income Taxes, in the Notes to Consolidated Financial Statements for information regarding our effective income tax rates.
Net income attributable to noncontrolling interests increased $26 million for the three months ended March 31, 2025, due to higher results from DCP LP primarily driven by the sale of GCX in January 2025. See Note 7—Investments, Loans and Long-Term Receivables, in the Notes to Consolidated Financial Statements for additional information regarding the sale of GCX.
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Segment Results
Midstream

| Three Months Ended March 31 |  |
| 2025 |  |  | 2024 |  |  |  |
| Millions of Dollars
Income Before Income Taxes |  |  |  |  |  |
Transportation | $ | 243 |  |  | 244 |  |  |  |
NGL | 508 |  |  | 310 |  |  |  |
Total Midstream | $ | 751 |  |  | 554 |  |  |  |

| Thousands of Barrels Daily
Transportation Volumes |  |  |  |  |  |
Pipelines* | 2,893 |  |  | 2,979 |  |  |  |
Terminals | 2,938 |  |  | 3,109 |  |  |  |
Operating Statistics |  |  |  |  |  |
Wellhead Volume (billion cubic feet per day)** | 4.1 |  |  | 4.4 |  |  |  |
NGL production** | 437 |  |  | 417 |  |  |  |
Pipeline Throughput–Y-Grade to Market*** | 704 |  |  | 714 |  |  |  |
NGL fractionated | 748 |  |  | 679 |  |  |  |

* Pipelines represent the sum of volumes transported through each separately tariffed consolidated pipeline segment, excluding NGL’s pipelines.
** Includes 100% of DCP Midstream Class A Segment.
*** Represents volumes delivered to major fractionation market hubs, including Mont Belvieu, Sweeny and Conway. Includes 100% of DCP Midstream Class A Segment and Phillips 66’s direct interest in DCP Sand Hills and DCP Southern Hills.

The Midstream segment provides crude oil and refined petroleum product transportation, terminaling and processing services; NGL production, transportation, storage, fractionation, processing, marketing and export services; natural gas gathering, compressing, treating, processing, storage, transportation and marketing services; and condensate recovery.
Results from our Midstream segment increased $197 million for the three months ended March 31, 2025.
Results from our Transportation business for the three months ended March 31, 2025, were in line with results for the three months ended March 31, 2024.
Results from our NGL business increased $198 million for the three months ended March 31, 2025, primarily due to a before-tax gain of $68 million recognized in the first quarter of 2025 on the sale of DCP LP’s 25% ownership interest in GCX, contributions from recently acquired gathering and processing assets, increased liquefied petroleum gas cargo volumes and margins, as well as, improved NGL and natural gas prices and increased fractionation volumes.
See the “Executive Overview and Business Environment” section for information on market factors impacting this quarter’s results.
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Chemicals

| Three Months Ended March 31 |  |
| 2025 |  |  | 2024 |  |  |  |
| Millions of Dollars
Income Before Income Taxes | $ | 113 |  |  | 205 |  |  |  |

| Millions of Pounds
CPChem Externally Marketed Sales Volumes* | 6,131 |  |  | 5,918 |  |  |  |
* Represents 100% of CPChem’s outside sales of produced petrochemical products, as well as commission sales from equity affiliates.

Olefins and Polyolefins Capacity Utilization (percent) | 100 | % |  | 96 |  |  |  |

The Chemicals segment consists of our 50% interest in CPChem, which we account for under the equity method. CPChem uses NGL and other feedstocks to produce petrochemicals. These products are then marketed and sold or used as feedstocks to produce plastics and other chemicals. CPChem produces and markets ethylene and other olefin products. Ethylene produced is primarily consumed within CPChem for the production of polyethylene, normal alpha olefins and polyethylene pipe. CPChem manufactures and/or markets aromatics and styrenics products, such as benzene, cyclohexane, styrene and polystyrene, as well as manufactures and/or markets a variety of specialty chemical products. Unless otherwise noted, amounts referenced below reflect our net 50% interest in CPChem.
Results from the Chemicals segment decreased $92 million for the three months ended March 31, 2025, primarily due to decreased polyethylene margins driven by lower sales prices and higher feedstock costs, lower volumes, and increased utility costs.
See the “Executive Overview and Business Environment” section for information on market factors impacting CPChem’s results.
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Refining

| Three Months Ended March 31 |  |
| 2025 |  |  | 2024 |  |  |  |
| Millions of Dollars
Income (Loss) Before Income Taxes |  |  |  |  |  |
Atlantic Basin/Europe | $ | (199) |  |  | 78 |  |  |  |
Gulf Coast | (333) |  |  | 120 |  |  |  |
Central Corridor | (50) |  |  | 213 |  |  |  |
West Coast | (355) |  |  | (195) |  |  |  |
Worldwide | $ | (937) |  |  | 216 |  |  |  |

| Dollars Per Barrel
Income (Loss) Before Income Taxes |  |  |  |  |  |
Atlantic Basin/Europe | $ | (5.15) |  |  | 1.66 |  |  |  |
Gulf Coast | (8.95) |  |  | 2.53 |  |  |  |
Central Corridor | (1.85) |  |  | 8.31 |  |  |  |
West Coast | (16.60) |  |  | (8.26) |  |  |  |
Worldwide | (7.53) |  |  | 1.50 |  |  |  |
Realized Refining Margins* |  |  |  |  |  |
Atlantic Basin/Europe | $ | 7.08 |  |  | 9.70 |  |  |  |
Gulf Coast | 4.43 |  |  | 10.95 |  |  |  |
Central Corridor | 8.29 |  |  | 12.56 |  |  |  |
West Coast | 7.12 |  |  | 10.60 |  |  |  |
Worldwide | 6.81 |  |  | 11.01 |  |  |  |

* See the “Non-GAAP Reconciliations” section for a reconciliation of this non-GAAP measure to the most directly comparable measure under generally accepted accounting principles in the United States (GAAP), income (loss) before income taxes per barrel.
In October 2024, we announced our intention to cease operations at our Los Angeles Refinery in the fourth quarter of 2025, and we are evaluating potential future uses of the property. See Note 2—Restructuring, in the Notes to Consolidated Financial Statements for additional information. In early 2024, we ceased crude operations at the San Francisco Refinery as part of the conversion of the refinery into the Rodeo Complex.
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| Thousands of Barrels Daily
| Three Months Ended March 31 |  |
Operating Statistics | 2025 |  | 2024 |  |  |  |
Refining operations* |  |  |  |  |  |
Atlantic Basin/Europe |  |  |  |  |  |
Crude oil capacity | 537 |  |  | 537 |  |  |  |
Crude oil processed | 359 |  |  | 472 |  |  |  |
Capacity utilization (percent) | 67 | % |  | 88 |  |  |  |
Refinery production | 435 |  |  | 522 |  |  |  |
Gulf Coast |  |  |  |  |  |
Crude oil capacity | 529 |  |  | 529 |  |  |  |
Crude oil processed | 369 |  |  | 475 |  |  |  |
Capacity utilization (percent) | 70 | % |  | 90 |  |  |  |
Refinery production | 409 |  |  | 526 |  |  |  |
Central Corridor |  |  |  |  |  |
Crude oil capacity | 531 |  |  | 531 |  |  |  |
Crude oil processed | 521 |  |  | 509 |  |  |  |
Capacity utilization (percent) | 98 | % |  | 96 |  |  |  |
Refinery production | 542 |  |  | 527 |  |  |  |
West Coast |  |  |  |  |  |
Crude oil capacity | 244 |  |  | 244 |  |  |  |
Crude oil processed | 228 |  |  | 244 |  |  |  |
Capacity utilization (percent) | 93 | % |  | 100 |  |  |  |
Refinery production | 236 |  |  | 257 |  |  |  |
Worldwide |  |  |  |  |  |
Crude oil capacity | 1,841 |  |  | 1,841 |  |  |  |
Crude oil processed | 1,477 |  |  | 1,700 |  |  |  |
Capacity utilization (percent) | 80 | % |  | 92 |  |  |  |
Refinery production | 1,622 |  |  | 1,832 |  |  |  |
* Includes our share of equity affiliates.

The Refining segment refines crude oil and other feedstocks into petroleum products, such as gasoline and distillates, including aviation fuels, at 11 refineries in the United States and Europe.
Results from our Refining segment decreased $1,153 million for the three months ended March 31, 2025, primarily due to lower realized margins as a result of declining market crack spreads, as well as lower volumes and higher costs driven by planned turnaround activity.
Our worldwide refining crude oil capacity utilization rate was 80% and 92% for the three months ended March 31, 2025 and 2024, respectively. The decrease for the three months ended March 31, 2025, was primarily due to higher turnaround activity. See the “Executive Overview and Business Environment” section for information on market factors impacting this quarter’s results.
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Marketing and Specialties

| Three Months Ended March 31 |  |
| 2025 |  |  | 2024 |  |  |  |
| Millions of Dollars
Income Before Income Taxes | $ | 1,282 |  |  | 366 |  |  |  |

| Dollars Per Barrel
Income Before Income Taxes |  |  |  |  |  |
U.S. | $ | 0.67 |  |  | 1.38 |  |  |  |
International | 39.88 |  |  | 2.94 |  |  |  |
Realized Marketing Fuel Margins* |  |  |  |  |  |
U.S. | $ | 1.36 |  |  | 1.60 |  |  |  |
International | 4.87 |  |  | 4.88 |  |  |  |

* See the “Non-GAAP Reconciliations” section for a reconciliation of this non-GAAP measure to the most directly comparable GAAP measure, income before income taxes per barrel.

| Dollars Per Gallon
U.S. Average Wholesale Prices* |  |  |  |  |  |
Gasoline | $ | 2.50 |  |  | 2.61 |  |  |  |
Distillates | 2.54 |  |  | 2.83 |  |  |  |
* On third-party branded petroleum product sales, excluding excise taxes. |  |  |  |  |  |

| Thousands of Barrels Daily
Marketing Refined Product Sales |  |  |  |  |  |
Gasoline | 1,194 |  |  | 1,215 |  |  |  |
Distillates | 906 |  |  | 968 |  |  |  |
Other | 40 |  |  | 46 |  |  |  |
| 2,140 |  |  | 2,229 |  |  |  |

The M&S segment purchases for resale and markets refined products, mainly in the United States and Europe. In addition, this segment includes the manufacturing and marketing of base oils and lubricants.
Results from the M&S segment increased $916 million for the three months ended March 31, 2025. The increase was primarily due to a before-tax gain of $1 billion associated with the sale of our investment in Coop, partially offset by lower domestic marketing fuel margins. Refer to Note 7—Investments, Loans and Long-Term Receivables, in the Notes to Consolidated Financial Statements for additional information regarding the sale of Coop.
See the “Executive Overview and Business Environment” section for information on marketing fuel margins and other market factors impacting this quarter’s results.
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Renewable Fuels

| Three Months Ended March 31 |  |
| 2025 |  |  | 2024 |  |  |  |
| Millions of Dollars
Loss Before Income Taxes | $ | (185) |  |  | (55) |  |  |  |

| Thousands of Barrels Daily
Operating Statistics |
Total Renewable Fuels Produced | 44 |  |  | 9 |  |  |  |
Total Renewable Fuel Sales | 63 |  |  | 34 |  |  |  |

Market Indicators |  |  |  |  |  |
Chicago Board of Trade (CBOT) soybean oil (dollars per pound) | $ | 0.44 |  |  | 0.47 |  |  |  |
California Low-Carbon Fuel Standard (LCFS) carbon credit (dollars per metric ton) | 66.28 |  |  | 63.86 |  |  |  |
California Air Resource Board (CARB) ultra-low-sulfur diesel (ULSD) - San Francisco (dollars per gallon) | 2.44 |  |  | 2.65 |  |  |  |
Biodiesel Renewable Identification Number (RIN) (dollars per RIN) | 0.79 |  |  | 0.58 |  |  |  |

The Renewable Fuels segment processes renewable feedstocks into renewable products at the Rodeo Complex and at our Humber Refinery. In addition, this segment includes the global activities to procure renewable feedstocks, manage certain regulatory credits, and market renewable fuels.
Results from the Renewable Fuels segment decreased $130 million for the three months ended March 31, 2025. The decrease was primarily driven by higher feedstock costs at the Rodeo Complex, partially offset by increased renewable fuels sales.
See the “Executive Overview and Business Environment” section for information on market factors impacting this quarter’s results.
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Corporate and Other

| Millions of Dollars
| Three Months Ended March 31 |  |  |
| 2025 |  |  | 2024 |  |  |  |  |  |  |
Loss Before Income Taxes |  |  |  |  |  |  |  |  |
Net interest expense | $ | (187) |  |  | (186) |  |  |  |  |  |  |
Corporate overhead and other | (174) |  |  | (141) |  |  |  |  |  |  |
NOVONIX | (15) |  |  | 5 |  |  |  |  |  |  |
Total Corporate and Other | $ | (376) |  |  | (322) |  |  |  |  |  |  |

Net interest expense consists of interest and financing expense, net of interest income and capitalized interest. Corporate overhead and other includes general and administrative expenses, technology costs, environmental costs associated with sites no longer in operation, foreign currency transaction gains and losses, and other costs not directly associated with an operating segment. Corporate and Other also includes the change in the fair value of our investment in NOVONIX. See Note 15—Fair Value Measurements, in the Notes to Consolidated Financial Statements for additional information regarding our investment in NOVONIX.
Net interest expense for the three months ended March 31, 2025, was in line with net interest expense for the three months ended March 31, 2024.
Corporate overhead and other costs increased $33 million for the three months ended March 31, 2025, primarily due to higher depreciation expense associated with information technology assets and a charge of $21 million associated with canceled projects, partially offset by lower employee-related expenses.
The fair value of our investment in NOVONIX declined by $15 million in the three months ended March 31, 2025, compared with an increase of $5 million in the three months ended March 31, 2024.
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CAPITAL RESOURCES AND LIQUIDITY
Financial Indicators

| Millions of Dollars, Except as Indicated
| March 31 2025 |  | December 31 2024
Cash and cash equivalents | $ | 1,489 |  |  | 1,738 |
Short-term debt | 1,061 |  |  | 1,831 |
Total debt | 18,803 |  |  | 20,062 |
Total equity | 28,353 |  |  | 28,463 |
Percent of total debt to capital* | 40% |  | 41
Percent of floating-rate debt to total debt | 3% |  | 9
* Capital includes total debt and total equity.

To meet our short- and long-term liquidity requirements, we use a variety of funding sources but rely primarily on cash generated from operating activities and debt financing. During the first three months of 2025, we generated $187 million of cash from operations. We funded capital expenditures and investments of $423 million and received proceeds from asset dispositions of $2 billion. Additionally, we repaid $1.3 billion of debt, paid $247 million to repurchase shares of our common stock and paid $469 million of dividends to our common stockholders. During the first three months of 2025, cash and cash equivalents decreased to $1.5 billion. At this time, we believe that our cash on hand, as well as the sources of liquidity described herein, will be sufficient to fund our obligations over the short- and long-term.
Significant Sources of Capital
Operating Activities
During the first three months of 2025, cash generated by operating activities was $187 million, compared with cash used in operations of $236 million for the first three months of 2024. The increase was primarily due to more favorable working capital impacts, partially offset by lower earnings.
Our short- and long-term operating cash flows are highly dependent upon refining and marketing margins, NGL prices and chemicals margins. Prices and margins in our industry are typically volatile and are driven by market conditions over which we have little or no control. Absent other mitigating factors, as these prices and margins fluctuate, we would expect a corresponding change in our operating cash flows.
The level and quality of output from our refineries also impacts our cash flows. Factors such as operating efficiency, maintenance turnarounds, market conditions, feedstock availability, and weather conditions can affect output. We actively manage the operations of our refineries, and any variability in their operations typically has not been as significant to cash flows as that caused by fluctuations in margins and prices.
Equity Affiliate Operating Distributions
Our operating cash flows are also impacted by distribution decisions made by our equity affiliates. During the first three months of 2025, cash from operations included aggregate distributions of $273 million from our equity affiliates, while cash from operations during the first three months of 2024 included aggregate distributions of $348 million from our equity affiliates. We cannot control the amount of future dividends from equity affiliates; therefore, future dividend payments by these equity affiliates are not assured.
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Debt Issuances
On February 28, 2024, Phillips 66 Company, a wholly owned subsidiary of Phillips 66, issued $1.5 billion aggregate principal amount of senior unsecured notes that are fully and unconditionally guaranteed by Phillips 66. The senior unsecured notes issuance consisted of:
•$600 million aggregate principal amount of 5.250% Senior Notes due 2031 (2031 Notes).
•$400 million aggregate principal amount of 5.300% Senior Notes due 2033 (Additional 2033 Notes).
•$500 million aggregate principal amount of 5.650% Senior Notes due 2054 (2054 Notes).
Interest on the 2031 Notes and 2054 Notes is payable semi-annually on June 15 and December 15 of each year and commenced on June 15, 2024. Interest on the Additional 2033 Notes is payable semi-annually on June 30 and December 30 of each year and commenced on June 30, 2024.
Accounts Receivable Securitization
On September 30, 2024, Phillips 66 Company entered into a 364-day, $500 million accounts receivable securitization facility (the Receivables Securitization Facility). Under the Receivables Securitization Facility, Phillips 66 Company sells or contributes on an ongoing basis, certain of its receivables, together with related security and interests in the proceeds thereof, to its wholly owned subsidiary, Phillips 66 Receivables LLC (P66 Receivables), a consolidated and bankruptcy-remote special purpose entity created for the sole purpose of transacting under the Receivables Securitization Facility. Under the Receivables Securitization Facility, P66 Receivables may borrow and incur indebtedness from, and/or sell certain receivables in an amount not to exceed $500 million in the aggregate, and will secure its obligations with a pledge of undivided interests in such receivables, together with related security and interests in the proceeds thereof, to PNC Bank, National Association, as Administrative Agent, for the benefit of the secured parties thereunder.
Sales of accounts receivables under the Receivables Securitization Facility meet the sale criteria under ASC 860, Transfers and Servicing, and are derecognized from the consolidated balance sheet. P66 Receivables guarantees payment, in full, for accounts receivables sold to the purchasers. For the three months ended March 31, 2025, we sold $130 million of accounts receivables for cash proceeds under the Receivables Securitization Facility. We recognized an immaterial charge associated with the transfer of financial assets, which is included as a component within the line item “Selling, general and administrative expense” on our consolidated statement of income during the three months ended March 31, 2025.
At March 31, 2025, we had utilized $130 million of our $500 million Receivable Securitization Facility from sold accounts receivables not yet remitted to the purchaser. Additionally, we had no outstanding borrowings at March 31, 2025. Therefore, at March 31, 2025, we had unused capacity of $370 million. At December 31, 2024, we had utilized the full $500 million of our Receivables Securitization Facility from $125 million of sold accounts receivables not yet remitted to the purchaser and $375 million of outstanding borrowings.
On April 1, 2025, Phillips 66 Company amended the Receivables Securitization Facility to, among other things, increase the maximum size of the Receivables Securitization Facility from $500 million to $1 billion.
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Credit Facilities and Commercial Paper
Phillips 66 and Phillips 66 Company
On January 13, 2025, we entered into a $200 million uncommitted credit facility (the 2025 Uncommitted Facility) with Phillips 66 Company as the borrower and Phillips 66 as the guarantor. The 2025 Uncommitted Facility contains covenants and events of default customary for unsecured uncommitted facilities. The 2025 Uncommitted Facility has no commitment fees or compensating balance requirements. Outstanding borrowings under the 2025 Uncommitted Facility bear interest at a rate of either (a) the adjusted term SOFR plus the applicable margin, (b) the adjusted daily simple SOFR plus the applicable margin or (c) the base rate, in each case plus the applicable margin. Each borrowing matures six months from the date of such borrowing. We may at any time prepay outstanding borrowings, in whole or in part, without premium or penalty. At March 31, 2025, no amount had been drawn under the 2025 Uncommitted Facility.
On June 25, 2024, we entered into a $400 million uncommitted credit facility (the Uncommitted Facility) with Phillips 66 Company as the borrower and Phillips 66 as the guarantor. The Uncommitted Facility contains covenants and events of default customary for unsecured uncommitted facilities. The Uncommitted Facility has no commitment fees or compensating balance requirements. Outstanding borrowings under the Uncommitted Facility bear interest at a rate of either (a) the adjusted term SOFR, (b) the adjusted daily simple SOFR or (c) the reference rate, in each case plus the applicable margin. Each borrowing matures six months from the date of such borrowing. We may at any time prepay outstanding borrowings, in whole or in part, without premium or penalty. At March 31, 2025, no amount had been drawn under the 2024 Uncommitted Facility, while at December 31, 2024, the entire $400 million had been drawn.
On February 28, 2024, we entered into a new $5 billion revolving credit agreement (the Facility) with Phillips 66 Company as the borrower and Phillips 66 as the guarantor and a scheduled maturity date of February 28, 2029. The Facility replaced our previous $5 billion revolving credit facility dated as of June 23, 2022, with Phillips 66 Company as the borrower and Phillips 66 as the guarantor, and the previous revolving credit facility was terminated. The Facility contains customary covenants similar to the previous revolving credit facility, including a maximum consolidated net debt-to-capitalization ratio of 65% as of the last day of each fiscal quarter. The Facility has customary events of default, such as nonpayment of principal when due; nonpayment of interest, fees or other amounts after grace periods; and violation of covenants. We may at any time prepay outstanding borrowings under the Facility, in whole or in part, without premium or penalty. We have the option to increase the overall capacity to $6 billion, subject to certain conditions. We also have the option to extend the scheduled maturity of the Facility for up to two additional one-year terms, subject to, among other things, the consent of the lenders holding the majority of the commitments and of each lender extending its commitment. Outstanding borrowings under the Facility bear interest at either: (a) the adjusted term SOFR (as described in the Facility) in effect from time to time plus the applicable margin; or (b) the reference rate (as described in the Facility) plus the applicable margin. The pricing levels for the commitment fee and interest-rate margins are determined based on the ratings in effect for our senior unsecured long-term debt from time to time. At March 31, 2025, and December 31, 2024, no amount had been drawn under the Facility.
Phillips 66 also has a $5 billion uncommitted commercial paper program for short-term working capital needs that is supported by the Facility. Commercial paper maturities are contractually limited to less than one year. At March 31, 2025, no borrowings were outstanding under this program, while at December 31, 2024, $435 million of commercial paper had been issued under this program.
DCP Midstream Class A Segment
On March 15, 2024, DCP LP terminated its $1.4 billion credit facility and its accounts receivable securitization facility that previously provided for up to $350 million of borrowing capacity. In conjunction with the termination of these facilities, DCP LP repaid $25 million in borrowings outstanding under its $1.4 billion credit facility and $350 million of borrowings outstanding under its accounts receivable securitization facility during the three months ended March 31, 2024.
Total Committed Capacity Available
At March 31, 2025, and December 31, 2024, we had approximately $5.4 billion and $4.6 billion, respectively, of total committed capacity available under the credit facilities described above.
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Investment Dispositions
On January 31, 2025, we sold our 49% ownership interest in Coop and settled the foreign currency forward contracts entered into in connection with the asset sale. We received cash proceeds of $1.2 billion, consisting of a sales price of $1.15 billion and a final dividend relating to financial year 2024 of $92 million from Coop that was paid on January 30, 2025.
On January 30, 2025, DCP LP sold its 25% ownership interest in GCX for cash proceeds of $853 million.
See Note 7—Investments, Loans and Long-Term Receivables, in the Notes to Consolidated Financial Statements for additional information regarding investment dispositions.
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Off-Balance Sheet Arrangements
Lease Residual Value Guarantees
Under the operating lease agreement for our headquarters facility in Houston, Texas, we have the option, at the end of the lease term in September 2025, to request to renew the lease, purchase the facility or assist the lessor in marketing it for resale. We have a residual value guarantee associated with the operating lease agreement with a maximum potential future exposure of $514 million at March 31, 2025. We also have residual value guarantees associated with railcar, airplane and truck leases with maximum potential future exposures totaling $176 million. These leases have remaining terms of one to ten years.
Dakota Access, LLC (Dakota Access) and Energy Transfer Crude Oil Company, LLC (ETCO)
In 2020, the trial court presiding over litigation brought by the Standing Rock Sioux Tribe (the Tribe) ordered the U.S. Army Corps of Engineers (USACE) to prepare an Environmental Impact Statement (EIS) addressing an easement under Lake Oahe in North Dakota. The trial court later vacated the easement. Although the easement is vacated, the USACE has no plans to stop pipeline operations while it proceeds with the EIS, and the Tribe’s request for a shutdown was denied in May 2021. In June 2021, the trial court dismissed the litigation entirely. Once the EIS is completed, new litigation or challenges may be filed.
In February 2022, the U.S. Supreme Court (the Supreme Court) denied Dakota Access’ writ of certiorari requesting the Supreme Court to review the trial court’s decision to order the EIS and vacate the easement. Therefore, the requirement to prepare the EIS stood. Also in February 2022, the Tribe withdrew as a cooperating agency, causing the USACE to halt the EIS process while the USACE engaged with the Tribe on their reasons for withdrawing.
The draft EIS process resumed in August 2022, and in September 2023, the USACE published its draft EIS for public comment. The USACE identified five potential outcomes but did not indicate which one it preferred. The options comprise two “no action” alternatives where the USACE would deny an easement to Dakota Access and require it to shut down the pipeline and either remove the pipe from under Lake Oahe or allow the pipeline to be abandoned-in-place under the lake. The USACE also identified three “action” alternatives; two of them contemplate that the USACE would reissue the easement to Dakota Access under essentially the same terms as 2017 with either the same or a larger volume of oil allowed through the pipeline, while the third alternative would require decommissioning of the current pipeline and construction of a new line 39 miles upstream from the current location.
The public comment period concluded on December 13, 2023. The USACE plans to review the comments and issue its final EIS in early 2026. The Record of Decision will follow within 30 to 60 days after the issuance of the final EIS. The final EIS must be completed before the USACE can reauthorize the easement for the pipeline. If reauthorization occurs, new litigation challenging the reauthorization may be filed.
In October 2024, the Tribe filed another lawsuit against the USACE in federal district court in Washington, D.C., again challenging USACE’s allowance of pipeline operations while the EIS process proceeds. In this lawsuit, the Tribe purports to introduce new evidence regarding the pipeline’s proximity to a reservoir and attempts to relitigate arguments about the need for injunctive relief to support its position that the Supreme Court should halt pipeline operations. A consortium of 13 states has joined Dakota Access as intervenors. The consortium argues that the pipeline reduces pollution compared to other modes of transportation and that Dakota Access is integral to the health of regional energy and agriculture markets. The Tribe’s prior request for a shutdown was denied in May 2021. This latest lawsuit seeking a shutdown does not change the current deadline for the issuance of the final EIS. Motions to Dismiss the latest lawsuit were filed by USACE, Dakota Access, and Intervenors and opposed by the Tribe. The parties are awaiting the district court’s decision. On March 19, 2025, the Tribe filed a notice in support of its latest lawsuit, indicating three additional facts for the district court to consider when making its ruling on the lawsuit. These facts relate to events regarding Energy Transfer LP’s conduct and third-party actions against it.
Dakota Access and ETCO have guaranteed repayment of senior unsecured notes issued by a wholly owned subsidiary of Dakota Access. On April 1, 2024, Dakota Access’ wholly owned subsidiary repaid $1 billion aggregate principal amount of its outstanding senior notes upon maturity. We funded our 25% share of the repayment, or $250 million, with a capital contribution of $171 million in March 2024 and $79 million of distributions we elected not to receive from Dakota Access in the first quarter of 2024. At March 31, 2025, the aggregate principal amount outstanding of Dakota Access’ senior unsecured notes was $850 million.
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In addition, Phillips 66 Partners LP (Phillips 66 Partners), a wholly owned subsidiary of Phillips 66, and its co-venturers in Dakota Access also provided a Contingent Equity Contribution Undertaking (CECU) in conjunction with the notes offering. Under the CECU, the co-venturers may be severally required to make proportionate equity contributions to Dakota Access if there is an unfavorable final judgment in the above-mentioned ongoing litigation. At March 31, 2025, our 25% share of the maximum potential equity contributions under the CECU was approximately $215 million. If the pipeline is required to cease operations, it may have a material adverse effect on our results of operations and cash flows. Should operations cease and Dakota Access and ETCO not have sufficient funds to pay its expenses, we also could be required to support our 25% share of the ongoing expenses, including scheduled interest payments on the notes of approximately $10 million annually, in addition to the potential obligations under the CECU at March 31, 2025.
See Note 7—Investments, Loans and Long-Term Receivables, in the Notes to Consolidated Financial Statements for additional information regarding our investments in Dakota Access and ETCO. See Note 12—Guarantees, in the Notes to Consolidated Financial Statements for additional information regarding our guarantees.
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Capital Requirements
Capital Expenditures and Investments
For information about our capital expenditures and investments, see the “Capital Spending” section below.
Debt Financing
Our debt balance at March 31, 2025, and December 31, 2024, was $18.8 billion and $20.1 billion, respectively. Our total debt-to-capital ratio was 40% and 41% at March 31, 2025, and December 31, 2024, respectively.
On February 18, 2025, upon maturity, Phillips 66 Partners repaid its 3.605% Senior Notes due February 2025 with an aggregate principal amount of $59 million.
Subsequent Midstream Acquisition
On April 1, 2025, we acquired all issued and outstanding equity interests in each of EPIC Y-Grade GP, LLC and EPIC Y-Grade, LP, together with their respective subsidiaries, which own various long haul natural gas liquids pipelines, fractionation facilities and distribution systems, for cash consideration of $2.2 billion, net of cash acquired. This acquisition was funded with cash and borrowings under our short-term liquidity facilities.
Dividends
On February 12, 2025, our Board of Directors declared a quarterly cash dividend of $1.15 per common share. This dividend was paid on March 5, 2025, to holders of record at the close of business on February 24, 2025. On April 21, 2025, our Board of Directors declared a quarterly cash dividend of $1.20 per common share. This dividend is payable on June 2, 2025, to shareholders of record as of the close of business on May 19, 2025.
Share Repurchases
Since July 2012, our Board of Directors has authorized an aggregate of $25 billion of repurchases of our outstanding common stock under our share repurchase program. Our share repurchase authorizations do not expire. Any future share repurchases will be made at the discretion of management and will depend on various factors including our share price, results of operations, financial condition and cash required for future business plans. For the three months ended March 31, 2025, we repurchased 2 million shares at an aggregate cost of approximately $0.2 billion. Since July 2012, we have repurchased 240 million shares under our share repurchase program at an aggregate cost of $21.8 billion. Shares of stock repurchased are held as treasury shares.
Employee Benefit Plan Contributions
During the three months ended March 31, 2025, we contributed $49 million to our U.S. pension and other postretirement benefit plans and $1 million to our international pension plans. We currently expect to make additional contributions of approximately $26 million to our U.S. pension and other postretirement benefit plans and approximately $4 million to our international pension plans during the remainder of 2025.
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Capital Spending

| Millions of Dollars
| Three Months Ended March 31
| 2025 |  |  | 2024 |
Capital Expenditures and Investments |  |  |
Midstream | $ | 216 |  |  | 255 |
Chemicals | — |  |  | — |
Refining | 176 |  |  | 135 |
Marketing and Specialties | 15 |  |  | 15 |
Renewable Fuels | 9 |  |  | 217 |
Corporate and Other | 7 |  |  | 6 |
Total Capital Expenditures and Investments | $ | 423 |  |  | 628 |
Selected Equity Affiliates* |  |  |
CPChem | 182 |  |  | 201 |
WRB | 21 |  |  | 24 |
| $ | 203 |  |  | 225 |
* Our share of joint ventures’ capital spending.

Midstream
During the first three months of 2025, capital spending in our Midstream segment was $216 million and included:
•Continued development of a second Dos Picos gas plant, further expanding our operations in the Permian Basin.
•Gathering and processing projects to further align our wellhead-to-market strategy.
•Spending associated with other reliability and maintenance projects in our Transportation and NGL businesses.
Chemicals
During the first three months of 2025, on a 100% basis, CPChem’s capital expenditures and investments were $363 million. Capital spending was primarily for the development of petrochemical projects on the U.S. Gulf Coast and in the Middle East, as well as sustaining, debottlenecking and optimization projects on existing assets. CPChem’s capital program was self-funded, and we expect CPChem to continue self-funding its capital program for the remainder of 2025.
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Refining
Capital spending for the Refining segment during the first three months of 2025 was $176 million. Major capital activities included installation of facilities to improve market capture at our refineries and capital spending to improve reliability at our refineries.
Marketing and Specialties
Capital spending for the M&S segment during the first three months of 2025 was $15 million, primarily for the continued development and enhancement of retail sites in Europe, marketing-related information technology enhancements, spend associated with marketing and commercial fleet fueling businesses on the U.S. West Coast, and reliability and maintenance projects for our Specialties business.
Renewable Fuels
Capital spending for the Renewable Fuels segment during the first three months of 2025 was $9 million. The capital spending was focused on increasing reliability, debottlenecking opportunities and improving feed flexibility on existing assets.
Corporate and Other
Capital spending for Corporate and Other during the first three months of 2025 was $7 million, primarily related to information technology.
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Contingencies
A number of lawsuits involving a variety of claims that arose in the ordinary course of business have been filed against us or are subject to indemnifications provided by us. We also may be required to remove or mitigate the effects on the environment of the placement, storage, disposal or release of certain chemical, mineral and petroleum substances at various active and inactive sites. We regularly assess the need for financial recognition or disclosure of these contingencies. In the case of all known contingencies (other than those related to income taxes), we accrue a liability when the loss is probable and the amount is reasonably estimable. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. We do not reduce these liabilities for potential insurance or third-party recoveries. If applicable, we accrue receivables for probable insurance or other third-party recoveries. In the case of income tax-related contingencies, we use a cumulative probability-weighted loss accrual in cases where sustaining a tax position is uncertain.
Other than with respect to the legal matters described herein, based on currently available information, we believe it is remote that future costs related to known contingent liability exposures will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures. Estimates particularly sensitive to future changes include contingent liabilities recorded for environmental remediation, tax and legal matters. Estimated future environmental remediation costs are subject to change due to such factors as the uncertain magnitude of cleanup costs, the unknown time and extent of such remedial actions that may be required, and the determination of our liability in proportion to that of other potentially responsible parties. Estimated future costs related to tax and legal matters are subject to change as events evolve and as additional information becomes available during the administrative and litigation processes.
Legal and Tax Matters
Our legal and tax matters are handled by our legal and tax organizations, respectively. These organizations apply their knowledge, experience and professional judgment to the specific characteristics of our cases and uncertain tax positions. We employ a litigation management process to manage and monitor legal proceedings. Our process facilitates the early evaluation and quantification of potential exposures in individual cases and enables the tracking of those cases that have been scheduled for trial and/or mediation. Based on professional judgment and experience in using these litigation management tools and available information about current developments in all our cases, our legal organization regularly assesses the adequacy of current accruals and determines if adjustment of existing accruals, or establishment of new accruals, is required. In the case of income tax-related contingencies, we monitor tax legislation and court decisions, the status of tax audits and the statute of limitations within which a taxing authority can assert a liability.
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Propel Fuels Litigation
In late 2017, as part of Phillips 66 Company’s evaluation of various opportunities in the renewable fuels business, Phillips 66 Company engaged with Propel Fuels, Inc. (Propel Fuels), a California company that distributes E85 and other alternative fuels through fueling kiosks. Ultimately, the parties were not able to reach an agreement and negotiations were terminated in August 2018. On February 17, 2022, Propel Fuels filed a lawsuit in the Superior Court of California, County of Alameda (the Propel Court), alleging that Phillips 66 Company misappropriated trade secrets related to Propel Fuels’ renewable fuels business during and after due diligence. On October 16, 2024, a jury returned a verdict against Phillips 66 Company for $604.9 million in compensatory damages and issued a willfulness finding. In 2025, the Propel Court is expected to rule on motions filed by Propel Fuels seeking exemplary damages and attorneys’ fees. Propel Fuels asked the Propel Court to grant treble damages and Phillips 66 Company filed a brief in opposition to that request. A hearing on the exemplary damages was held on March 4, 2025. Also in 2025, the Propel Court is expected to rule on motions to be filed by Phillips 66 Company for a judgment in its favor as a matter of law, or in the alternative to reduce the jury’s verdict or to grant a new trial. Phillips 66 Company denies any wrongdoing and intends to vigorously defend its position. As a result of the jury verdict in October 2024, the Company recorded an accrual of $604.9 million during the third quarter of 2024, which was reported in the M&S segment. The accrued amount is reflected as “Other liabilities and deferred credits” on our consolidated balance sheet as of March 31, 2025, and December 31, 2024. However, it is reasonably possible that the estimate of the loss could change based on the progression of the case, including the appeals process. Because of the uncertainties associated with ongoing litigation, we are unable to estimate the range of reasonably possible loss that may be attributable to exemplary damages, if any, in excess of the amount accrued. If information were to become available that would allow us to reasonably estimate a range of potential exposure in an amount higher or lower than the amount already accrued, we would adjust our accrued liabilities accordingly. While Phillips 66 Company believes the jury verdict is not legally or factually supported and intends to pursue post-judgment remedies and file an appeal, there can be no assurances that such defense efforts will be successful. To the extent Phillips 66 Company is required to pay exemplary damages, it may have a material adverse effect on our financial position and results of operations.
Environmental
Like other companies in our industry, we are subject to numerous international, federal, state and local environmental laws and regulations. For a discussion of the most significant international and federal environmental laws and regulations to which we are subject, see the “Environmental” section in Management’s Discussion and Analysis of Financial Condition and Results of Operations in our 2024 Annual Report on Form 10-K.
We are required to purchase RINs in the open market to satisfy the portion of our obligation under the Renewable Fuel Standard (RFS) that is not fulfilled by blending renewable fuels into the motor fuels we produce. For the three months ended March 31, 2025, we were able to fully satisfy our obligations under the RFS through blending renewable fuels into the motor fuel we produce. For the three months ended March 31, 2024, we incurred expenses of $93 million associated with our obligation to purchase RINs in the open market to comply with the RFS for our wholly owned refineries. These expenses are included in the “Purchased crude oil and products” line item on our consolidated statement of income. Our jointly owned refineries also incurred expenses associated with the purchase of RINs in the open market, of which our share was $74 million and $59 million for the three months ended March 31, 2025 and 2024, respectively. These expenses are included in the “Equity in earnings of affiliates” line item on our consolidated statement of income. The amount of these expenses and fluctuations between periods is primarily driven by the market price of RINs, refinery and renewable fuels production, blending activities and renewable volume obligation requirements.
We occasionally receive requests for information or notices of potential liability from the Environmental Protection Agency (EPA) and state environmental agencies alleging that we are a potentially responsible party under the Federal Comprehensive Environmental Response, Compensation and Liability Act (CERCLA) or an equivalent state statute. On occasion, we also have been made a party to cost recovery litigation by those agencies or by private parties. These requests, notices and lawsuits assert potential liability for remediation costs at various sites that typically are not owned by us, but allegedly contain wastes attributable to our past operations. At March 31, 2025, and December 31, 2024, we reported that we had been notified of potential liability under CERCLA and comparable state laws at 19 sites within the United States and Puerto Rico.
Notwithstanding any of the foregoing, and as with other companies engaged in similar businesses, environmental costs and liabilities are inherent concerns in certain of our operations and products, and there can be no assurance that those costs and liabilities will not be material. However, we currently do not expect any material adverse effect on our results of operations or financial position as a result of compliance with current environmental laws and regulations.
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Climate Change
There has been a broad range of proposed or promulgated state, national and international laws focusing on greenhouse gas (GHG) emissions reduction, including various regulations proposed or issued by the EPA. These proposed or promulgated laws apply or could apply in states and/or countries where we have interests or may have interests in the future. Laws regulating GHG emissions continue to evolve, and while it is not possible to accurately estimate either a timetable for implementation or our future compliance costs relating to implementation, such laws potentially could have a material impact on our results of operations and financial condition as a result of increasing costs of compliance, lengthening project implementation and agency reviews, or reducing demand for certain hydrocarbon products.
For examples of legislation and regulation or precursors for possible regulation that do or could affect our operations, see the “Climate Change” section in Management’s Discussion and Analysis of Financial Condition and Results of Operations in our 2024 Annual Report on Form 10-K.
We consider and take into account anticipated future GHG emissions in designing and developing major facilities and projects, and implement energy efficiency initiatives to reduce GHG emissions. Data on our GHG emissions, legal requirements regulating such emissions, and the possible physical effects of climate change on our coastal assets are incorporated into our planning, investment, and risk management decision-making. We are working to continuously improve operational and energy efficiency through resource and energy conservation efforts throughout our operations.
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GUARANTOR FINANCIAL INFORMATION
We have various cross guarantees between Phillips 66 and its wholly owned subsidiary Phillips 66 Company (together, the Obligor Group) with respect to publicly held debt securities. Phillips 66 conducts substantially all of its operations through subsidiaries, including Phillips 66 Company, and those subsidiaries generate substantially all of its operating income and cash flow. Phillips 66 has fully and unconditionally guaranteed the payment obligations of Phillips 66 Company with respect to its publicly held debt securities. In addition, Phillips 66 Company has fully and unconditionally guaranteed the payment obligations of Phillips 66 with respect to its publicly held debt securities. All guarantees are full and unconditional. At March 31, 2025, $14.4 billion of senior unsecured notes outstanding has been guaranteed by the Obligor Group.
Summarized financial information of the Obligor Group is presented on a combined basis. Intercompany transactions among the members of the Obligor Group have been eliminated. The financial information of non-guarantor subsidiaries has been excluded from the summarized financial information. Significant intercompany transactions and receivable/payable balances between the Obligor Group and non-guarantor subsidiaries are presented separately in the summarized financial information.
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The summarized results of operations for the three months ended March 31, 2025, and the summarized financial position at March 31, 2025, and December 31, 2024, for the Obligor Group on a combined basis were:

Summarized Combined Statement of Loss | Millions of Dollars
| Three Months Ended March 31, 2025
Sales and other operating revenues | 22,482 |
Revenues and other income—non-guarantor subsidiaries | 2,370 |
Purchased crude oil and products—third parties | 13,684 |
Purchased crude oil and products—related parties | 3,990 |
Purchased crude oil and products—non-guarantor subsidiaries | 6,037 |
Loss before income taxes | (1,385) |
Net loss | (1,073) |

Summarized Combined Balance Sheet | Millions of Dollars |
| March 31 2025 |  | December 31 2024 |
Accounts and notes receivable—third parties | 752 |  |  | 1,229 |  |
Accounts and notes receivable—related parties | 1,518 |  |  | 1,422 |  |
Due from non-guarantor subsidiaries, current | 2,866 |  |  | 3,102 |  |
Total current assets | 10,691 |  |  | 10,228 |  |
Investments and long-term receivables | 10,601 |  |  | 10,640 |  |
Net properties, plants and equipment | 11,846 |  |  | 12,186 |  |
Goodwill | 1,047 |  |  | 1,047 |  |
Due from non-guarantor subsidiaries, noncurrent | 390 |  |  | 1,171 |  |
Other assets associated with non-guarantor subsidiaries | 1,237 |  |  | 1,306 |  |
Total noncurrent assets | 27,161 |  |  | 28,380 |  |
Total assets | 37,852 |  |  | 38,608 |  |
Due to non-guarantor subsidiaries, current | 6,342 |  |  | 5,398 |  |
Total current liabilities | 14,344 |  |  | 14,236 |  |
Long-term debt | 14,485 |  |  | 14,969 |  |
Due to non-guarantor subsidiaries, noncurrent | 8,042 |  |  | 8,319 |  |
Total noncurrent liabilities | 28,866 |  |  | 29,640 |  |
Total liabilities | 43,210 |  |  | 43,876 |  |
Total equity | (5,358) |  |  | (5,268) |  |
Total liabilities and equity | 37,852 |  |  | 38,608 |  |

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NON-GAAP RECONCILIATIONS
Refining
Our realized refining margins measure the difference between (a) sales and other operating revenues derived from the sale of petroleum products manufactured at our refineries and (b) costs of feedstocks, primarily crude oil, used to produce the petroleum products. The realized refining margins are adjusted to include our proportional share of our joint venture refineries’ realized margins, as well as to exclude those items that are not representative of the underlying operating performance of a period, which we call “special items.” The realized refining margins are converted to a per-barrel basis by dividing them by total refinery processed inputs (primarily crude oil) measured on a barrel basis, including our share of inputs processed by our joint venture refineries. Our realized refining margin per barrel is intended to be comparable with industry refining margins, which are known as “crack spreads.” As discussed in “Executive Overview and Business Environment—Business Environment,” industry crack spreads measure the difference between market prices for refined petroleum products and crude oil. We believe realized refining margin per barrel calculated on a similar basis as industry crack spreads provides a useful measure of how well we performed relative to benchmark industry refining margins.
The GAAP performance measure most directly comparable to realized refining margin per barrel is the Refining segment’s “income (loss) before income taxes per barrel.” Realized refining margin per barrel excludes items that are typically included in a manufacturer’s gross margin, such as depreciation and operating expenses, and other items used to determine income (loss) before income taxes, such as general and administrative expenses. It also includes our proportional share of joint venture refineries’ realized refining margins and excludes special items. Because realized refining margin per barrel is calculated in this manner, and because realized refining margin per barrel may be defined differently by other companies in our industry, it has limitations as an analytical tool. Following are reconciliations of income (loss) before income taxes to realized refining margins:
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| Millions of Dollars, Except as Indicated
Realized Refining Margins | Atlantic Basin/ Europe | Gulf Coast | Central Corridor | West Coast | Worldwide
Three Months Ended March 31, 2025 |  |  |  |  |
Loss before income taxes | $ | (199) |  | (333) |  | (50) |  | (355) |  | (937) |
Plus: |  |  |  |  |
Taxes other than income taxes | 22 |  | 35 |  | 26 |  | 27 |  | 110 |
Depreciation, amortization and impairments | 56 |  | 72 |  | 41 |  | 287 |  | 456 |
Selling, general and administrative expenses | 6 |  | 9 |  | 23 |  | 8 |  | 46 |
Operating expenses | 373 |  | 381 |  | 148 |  | 172 |  | 1,074 |
Equity in losses of affiliates | 2 |  | — |  | 103 |  | — |  | 105 |
Other segment (income) expense, net | (6) |  | 1 |  | (12) |  | 12 |  | (5) |
Proportional share of refining gross margins contributed by equity affiliates | 21 |  | — |  | 120 |  | — |  | 141 |
Realized refining margins | $ | 275 |  | 165 |  | 399 |  | 151 |  | 990 |
Total processed inputs (thousands of barrels) | 38,716 |  | 37,206 |  | 27,169 |  | 21,362 |  | 124,453 |
Adjusted total processed inputs (thousands of barrels)* | 38,716 |  | 37,206 |  | 48,275 |  | 21,362 |  | 145,559 |
Loss before income taxes per barrel (dollars per barrel)** | $ | (5.15) |  | (8.95) |  | (1.85) |  | (16.60) |  | (7.53) |
Realized refining margins (dollars per barrel)*** | 7.08 |  | 4.43 |  | 8.29 |  | 7.12 |  | 6.81 |
Three Months Ended March 31, 2024 |  |  |  |  |
Income (loss) before income taxes | $ | 78 |  | 120 |  | 213 |  | (195) |  | 216 |
Plus: |  |  |  |  |
Taxes other than income taxes | 24 |  | 38 |  | 28 |  | 31 |  | 121 |
Depreciation, amortization and impairments | 52 |  | 62 |  | 44 |  | 156 |  | 314 |
Selling, general and administrative expenses | 3 |  | 6 |  | 24 |  | 5 |  | 38 |
Operating expenses | 251 |  | 301 |  | 143 |  | 258 |  | 953 |
Equity in (earnings) losses of affiliates | 1 |  | (1) |  | (108) |  | — |  | (108) |
Other segment (income) expense, net | 13 |  | 1 |  | (40) |  | (4) |  | (30) |
Proportional share of refining gross margins contributed by equity affiliates | 33 |  | — |  | 298 |  | — |  | 331 |
Special items: |  |  |  |  |
Legal settlement | — |  | (7) |  | — |  | — |  | (7) |
Realized refining margins | $ | 455 |  | 520 |  | 602 |  | 251 |  | 1,828 |
Total processed inputs (thousands of barrels) | 46,911 |  | 47,492 |  | 25,658 |  | 23,639 |  | 143,700 |
Adjusted total processed inputs (thousands of barrels)* | 46,911 |  | 47,492 |  | 47,912 |  | 23,639 |  | 165,954 |
Income before income taxes per barrel (dollars per barrel)** | $ | 1.66 |  | 2.53 |  | 8.31 |  | (8.26) |  | 1.50 |
Realized refining margins (dollars per barrel)*** | 9.70 |  | 10.95 |  | 12.56 |  | 10.60 |  | 11.01 |
* Adjusted total processed inputs include our proportional share of processed inputs of an equity affiliate.
** Income (loss) before income taxes divided by total processed inputs.
*** Realized refining margins per barrel, as presented, are calculated using the underlying realized refining margin amounts, in dollars, divided by adjusted total processed inputs, in barrels. As such, recalculated per barrel amounts using the rounded margins and barrels presented may differ from the presented per barrel amounts.

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Marketing
Our realized marketing fuel margins measure the difference between (a) sales and other operating revenues derived from the sale of fuels in our M&S segment and (b) costs of those fuels. The realized marketing fuel margins are adjusted to exclude those items that are not representative of the underlying operating performance of a period, which we call “special items.” The realized marketing fuel margins are converted to a per-barrel basis by dividing them by sales volumes measured on a barrel basis. We believe realized marketing fuel margin per barrel demonstrates the value uplift our marketing operations provide by optimizing the placement and ultimate sale of our facilities’ fuel production.
Within the M&S segment, the GAAP performance measure most directly comparable to realized marketing fuel margin per barrel is the marketing business’ “income before income taxes per barrel.” Realized marketing fuel margin per barrel excludes items that are typically included in gross margin, such as depreciation and operating expenses, and other items used to determine income before income taxes, such as general and administrative expenses. Because realized marketing fuel margin per barrel excludes these items, and because realized marketing fuel margin per barrel may be defined differently by other companies in our industry, it has limitations as an analytical tool. Following are reconciliations of income before income taxes to realized marketing fuel margins:

| Millions of Dollars, Except as Indicated
| Three Months Ended March 31, 2025 |  | Three Months Ended March 31, 2024
| U.S. | International |  | U.S. | International
Realized Marketing Fuel Margins |  |  |  |  |
Income before income taxes | $ | 111 |  | 1,117 |  |  | 242 |  | 81 |
Plus: |  |  |  |  |
Depreciation and amortization | 13 |  | 2 |  |  | 10 |  | 18 |
Selling, general and administrative expenses | 203 |  | 65 |  |  | 186 |  | 64 |
Equity in earnings of affiliates | (7) |  | (8) |  |  | (2) |  | (24) |
Other operating revenues* | (105) |  | (12) |  |  | (108) |  | (6) |
Other expense, net | 9 |  | 3 |  |  | 11 |  | 15 |
Special items: |  |  |  |  |
Net gain on asset disposition | — |  | (1,017) |  |  | — |  | — |
Legal settlement | — |  | — |  |  | (59) |  | — |
Marketing margins | 224 |  | 150 |  |  | 280 |  | 148 |
Less: margin for nonfuel related sales | — |  | 14 |  |  | — |  | 13 |
Realized marketing fuel margins | $ | 224 |  | 136 |  |  | 280 |  | 135 |
Total fuel sales volumes (thousands of barrels) | 164,499 |  | 28,011 |  |  | 175,269 |  | 27,590 |
Income before income taxes per barrel (dollars per barrel) | $ | 0.67 |  | 39.88 |  |  | 1.38 | 2.94 |
Realized marketing fuel margins (dollars per barrel)** | 1.36 |  | 4.87 |  |  | 1.60 | 4.88 |
* Includes other nonfuel revenues and expenses.
** Realized marketing fuel margins per barrel, as presented, are calculated using the underlying realized marketing fuel margin amounts, in dollars, divided by sales volumes, in barrels. As such, recalculated per barrel amounts using the rounded margins and barrels presented may differ from the presented per barrel amounts.

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CAUTIONARY STATEMENT FOR THE PURPOSES OF THE “SAFE HARBOR” PROVISIONS OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995
This report includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934, as amended (the Act). You can normally identify our forward-looking statements by the words “anticipate,” “estimate,” “believe,” “budget,” “continue,” “could,” “intend,” “may,” “plan,” “potential,” “predict,” “seek,” “should,” “will,” “would,” “expect,” “objective,” “projection,” “forecast,” “goal,” “guidance,” “outlook,” “effort,” “target,” “priorities” and similar expressions that convey the prospective nature of events or outcomes, but the absence of such words does not mean a statement is not forward-looking.
We based these forward-looking statements on our current expectations, estimates and projections about us, our operations, our joint ventures and entities in which we have equity interests, as well as the industries in which we and they operate, and our sustainability-related plans and goals. We caution you not to place undue reliance on these forward-looking statements, which speak only as of the date of this report, as they are not guarantees of future performance and involve assumptions that, while made in good faith, may prove to be incorrect, and involve risks and uncertainties we cannot predict. In addition, we based many of these forward-looking statements on assumptions about future events that may prove to be inaccurate. Accordingly, our actual outcomes and results may differ materially from what we have expressed or forecasted in any forward-looking statement. Our sustainability-related goals are not guarantees or promises and may change. Statements regarding our goals are not guarantees or promises that they will be met. The information included in, and any issues identified as material for purposes of, our sustainability reports shall not be considered material for U.S. Securities and Exchange Commission reporting purposes. Factors that could cause actual results to differ materially from those in our forward-looking statements include:
•Fluctuations in market conditions and demand impacting the prices of NGL, crude oil, refined petroleum products, renewable fuels, renewable feedstocks and natural gas prices and changes in refined product, marketing and petrochemical margins.
•Changes in governmental policies relating to NGL, crude oil, natural gas, refined petroleum or renewable fuels products pricing, regulation or taxation, including exports.
•Capacity constraints in, or other limitations on, the pipelines, storage and fractionation facilities to which we deliver natural gas or NGL and the availability of alternative markets and arrangements for our natural gas and NGL.
•Actions taken by Organization of the Petroleum Exporting Countries (OPEC) and non-OPEC oil producing countries impacting crude oil production and correspondingly, commodity prices.
•Unexpected changes in costs or technical requirements for constructing, modifying or operating our facilities or transporting our products.
•Unexpected technological or commercial difficulties in manufacturing, refining or transporting our products, including chemical products.
•Changes in the cost or availability of adequate and reliable transportation for our NGL, crude oil, natural gas and refined petroleum and renewable fuels products.
•The level and success of producers’ drilling plans and the amount and quality of production volumes around our midstream assets.
•Our ability to timely obtain or maintain permits, including those necessary for capital projects.
•Our ability to comply with government regulations or make capital expenditures required to maintain compliance.
•Our ability to realize sustained savings and cost reductions from the company’s business transformation initiatives.
•Changes to government policies relating to renewable fuels, climate change and GHG emissions that adversely affect programs like the renewable fuel standards program, low carbon fuel standards and tax credits for biofuels.
•Domestic and international economic and political developments including armed hostilities, such as the war in Eastern Europe, instability in the financial services and banking sector, excess inflation, expropriation of assets and changes in fiscal policy, including interest rates.
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•The impact on commercial activity and demand for our products from any widespread public health crisis, as well as the extent and duration of recovery of economies and demand for our products following any such crisis.
•Failure to complete definitive agreements and feasibility studies for, and to complete construction of, announced and future capital projects on time and within budget.
•Our ability to successfully complete, or any material delay in the completion of, any asset dispositions, acquisitions, shutdowns or conversions that we may pursue, including the receipt of any necessary regulatory approvals or permits related to such action.
•Potential disruption or interruption of our operations or those of our joint ventures due to litigation or governmental or regulatory action.
•Damage to our facilities due to accidents, weather and climate events, civil unrest, insurrections, political events, terrorism or cyberattacks.
•Our sustainability goals, including reducing our GHG emissions intensity, developing and protecting new technologies, and commercializing lower-carbon opportunities.
•Failure of new products and services to achieve market acceptance.
•International monetary conditions and exchange controls.
•Substantial investments required, or reduced demand for products, as a result of existing or future environmental rules and regulations, including GHG emissions reductions and reduced consumer demand for refined petroleum products.
•Liability resulting from pending or future litigation or other legal proceedings.
•Liability for remedial actions, including removal and reclamation obligations under environmental regulations.
•Changes in tax, environmental and other laws and regulations (including alternative energy mandates) applicable to our business.
•Economic, political and regulatory conditions domestically and internationally, including imposition of tariffs or other tax incentives or disincentives.
•Political and societal concerns about climate change that could result in changes to our business or operations or increase expenditures, including litigation-related expenses.
•Changes in estimates or projections used to assess fair value of intangible assets, goodwill, and properties, plants and equipment and/or strategic decisions or other developments with respect to our asset portfolio that cause impairment charges.
•Limited access to capital or significantly higher cost of capital related to changes to our credit profile or illiquidity or uncertainty in the domestic or international financial markets.
•The creditworthiness of our customers and the counterparties to our transactions, including the impact of bankruptcies.
•Cybersecurity incidents or other disruptions that compromise our information and expose us to liability.
•The operation, financing and distribution decisions of our joint ventures that we do not control.
•The potential impact of activist shareholder actions or tactics.
•The factors generally described in Item 1A.—Risk Factors in our 2024 Annual Report on Form 10-K.
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Item 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Our commodity price risk and interest rate risk at March 31, 2025, did not differ materially from the risks disclosed under Item 7A of our 2024 Annual Report on Form 10-K.
Item 4. CONTROLS AND PROCEDURES
We maintain disclosure controls and procedures designed to ensure that information required to be disclosed in reports we file or submit under the Act, is recorded, processed, summarized and reported within the time periods specified in U.S. Securities and Exchange Commission rules and forms, and that such information is accumulated and communicated to management, including our principal executive and principal financial officers, as appropriate, to allow timely decisions regarding required disclosure. As of March 31, 2025, with the participation of management, our Chairman and Chief Executive Officer and our Executive Vice President and Chief Financial Officer carried out an evaluation, pursuant to Rule 13a-15(b) of the Act, of the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) of the Act). Based upon that evaluation, our Chairman and Chief Executive Officer and our Executive Vice President and Chief Financial Officer concluded that our disclosure controls and procedures were operating effectively as of March 31, 2025.
There have been no changes in our internal control over financial reporting, as defined in Rule 13a-15(f) of the Act, in the quarterly period ended March 31, 2025, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
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PART II. OTHER INFORMATION
Item 1. LEGAL PROCEEDINGS
From time to time, we may be involved in litigation and claims arising out of our operations in the normal course of business. Additionally, we have elected a $1 million threshold to disclose certain proceedings arising under federal, state or local environmental laws when a governmental authority is a party to the proceedings. During the first quarter of 2025, there were no new matters and one material development with respect to matters previously reported. Except as otherwise set forth herein, we do not currently believe that the eventual outcome of any matters previously reported, but still unresolved, individually or in the aggregate, could have a material adverse effect on our business, financial condition, results of operations or cash flows.
Further, our U.S. refineries are implementing two separate consent decrees, regarding alleged violations of the Federal Clean Air Act, with the EPA, five states and one local air pollution agency. Some of the requirements and limitations contained in the decrees provide for stipulated penalties for violations. Stipulated penalties under the decrees are not automatic, but must be requested by one of the agency signatories. As part of periodic reports under the decrees or other reports required by permits or regulations, we occasionally report matters that could be subject to a request for stipulated penalties. If a specific request for stipulated penalties meeting the reporting threshold set forth in U.S. Securities and Exchange Commission rules is made pursuant to these decrees based on a given reported exceedance, we will separately report that matter and the amount of the proposed penalty.
Matters Previously Reported (unresolved or resolved since the 2024 Annual Report on Form 10-K)
As described further in the “Legal Proceedings” section of Note 13—Contingencies and Commitments, in the Notes to Consolidated Financial Statements, on February 17, 2022, Propel Fuels, Inc. (Propel Fuels) filed a lawsuit in the Superior Court of California, County of Alameda (the Propel Court), alleging that Phillips 66 Company misappropriated trade secrets related to Propel Fuels’ renewable fuels business. On October 16, 2024, a jury returned a verdict against Phillips 66 Company for $604.9 million in compensatory damages and issued a willfulness finding. In 2025, the Propel Court is expected to rule on motions filed by Propel Fuels seeking exemplary damages and attorneys’ fees. Propel Fuels asked the Propel Court to grant treble damages and Phillips 66 Company filed a brief in opposition to that request. A hearing on the exemplary damages was held on March 4, 2025. Also in 2025, the Propel Court is expected to rule on motions to be filed by Phillips 66 Company for a judgment in its favor as a matter of law, or in the alternative to reduce the jury’s verdict or to grant a new trial. Phillips 66 Company denies any wrongdoing and intends to vigorously defend its position. While Phillips 66 Company believes the jury verdict is not legally or factually supported and intends to pursue post-judgment remedies and file an appeal, there can be no assurances that such defense efforts will be successful. To the extent Phillips 66 Company is required to pay exemplary damages, it may have a material adverse effect on our financial position and results of operations.
Dakota Access, LLC (Dakota Access) and Energy Transfer Crude Oil Company, LLC (ETCO)
See the “Dakota Access, LLC (Dakota Access) and Energy Transfer Crude Oil Company, LLC (ETCO)” section of Note 7—Investments, Loans and Long-Term Receivables and Note 13—Contingencies and Commitments, in the Notes to Consolidated Financial Statements for additional information regarding Legal Proceedings and other regulatory actions.
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Item 1A. RISK FACTORS
There have been no material changes from the risk factors disclosed in Item 1A of our 2024 Annual Report on Form 10-K.
Item 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
Issuer Purchases of Equity Securities

|  |  |  |  |  | Millions of Dollars
Period | Total Number of Shares Purchased* |  | Average Price Paid per Share** | Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs*** |  | Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs
January 1-31, 2025 | 977,767 |  |  | $ | 119.74 |  | 977,767 |  | $ | 3,378 |
February 1-28, 2025 | 503,422 |  |  | 126.63 |  | 503,422 |  | 3,314 |
March 1-31, 2025 | 515,404 |  |  | 126.28 |  | 515,404 |  | 3,249 |
Total | 1,996,593 |  |  | $ | 123.16 |  | 1,996,593 |  |
* Includes repurchase of shares of common stock from company employees in connection with the company’s broad-based employee incentive plans, when applicable.
** Average price paid per share includes excise taxes.
*** Since the inception of our share repurchase program in 2012, our Board of Directors has authorized an aggregate of $25 billion of repurchases of our outstanding common stock. Our share repurchase authorizations do not expire. Any future share repurchases will be made at the discretion of management and will depend on various factors including our share price, results of operations, financial condition and cash required for future business plans. Shares of stock repurchased are held as treasury shares.

Item 5. OTHER INFORMATION
On February 12, 2025, Vanessa A. Sutherland, Executive Vice President, Government Affairs, General Counsel and Corporate Secretary, adopted a trading plan intended to satisfy Rule 10b5-1(c) under the Act, providing for the sale of up to 21,967 shares of our common stock between May 15, 2025 and May 15, 2026.
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Item 6. EXHIBITS

|  |  | Incorporated by Reference |
Exhibit Number |  | Exhibit Description | Form | Exhibit Number | Filing Date | SEC File No. |  |  |  |
3.1 |  | Amended and Restated Certificate of Incorporation of Phillips 66. | 8-K | 3.1 | 05/01/2012 | 001-35349 |  |  |  |
3.2 |  | Amended and Restated By-Laws of Phillips 66. | 8-K | 3.1 | 12/09/2022 | 001-35349 |  |  |  |
10.1 |  | Second Amendment to Receivables Purchase and Financing Agreement, dated as of April 1, 2025, among Phillips 66 Receivables LLC, the persons from time to time party thereto as Purchaser/Lenders, PNC Bank, National Association, as Administrative Agent, Phillips 66 Company, as servicer, and PNC Capital Markets LLC, as structuring agent. | 8-K | 10.1 | 04/01/2025 | 001-35349 |  |  |  |
10.2* |  | Form of Restricted Stock or Restricted Stock Unit Award Agreement under the 2022 Omnibus Stock Performance Incentive Plan of Phillips 66.** |  |  |  |  |  |  |  |
10.3* |  | Form of Performance Share Unit Award Agreement under the 2022 Omnibus Stock and Performance Incentive Plan of Phillips 66.** |  |  |  |  |  |  |  |
22* |  | List of Guarantor Subsidiaries. |  |  |  |  |  |  |  |
31.1* |  | Certification of Chief Executive Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934. |  |  |  |  |  |  |  |
31.2* |  | Certification of Chief Financial Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934. |  |  |  |  |  |  |  |
32*** |  | Certifications pursuant to 18 U.S.C. Section 1350. |  |  |  |  |  |  |  |
101.INS* |  | Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document. |  |  |  |  |  |  |  |
101.SCH* |  | Inline XBRL Schema Document. |  |  |  |  |  |  |  |
101.CAL* |  | Inline XBRL Calculation Linkbase Document. |  |  |  |  |  |  |  |
101.LAB* |  | Inline XBRL Labels Linkbase Document. |  |  |  |  |  |  |  |
101.PRE* |  | Inline XBRL Presentation Linkbase Document. |  |  |  |  |  |  |  |
101.DEF* |  | Inline XBRL Definition Linkbase Document. |  |  |  |  |  |  |  |
104* |  | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101). |  |  |  |  |  |  |  |
* Filed herewith. |  |  |  |  |  |  |  |
** Management contracts and compensatory plans or arrangements. |  |  |  |  |  |  |  |
*** Furnished herewith. |  |  |  |  |  |  |  |

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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

|  | PHILLIPS 66
|  | /s/ Ann M. Kluppel
|  | Ann M. Kluppel Vice President and Controller (Chief Accounting and Duly Authorized Officer)

Date: April 25, 2025
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