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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 endedJune 30, 20202021
or
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period fromto
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)
281-293-6600
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each classTrading Symbol(s)Name of each exchange on which registered
Common Stock, $0.01 Par ValuePSXNew 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 filerAccelerated filerNon-accelerated filer
Smaller reporting companyEmerging 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 436,696,660437,989,408 shares of common stock, $0.01 par value, outstanding as of June 30, 2020.2021.


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PHILLIPS 66

TABLE OF CONTENTS
 
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Table of Contents
PART I. FINANCIAL INFORMATION
Item 1. FINANCIAL STATEMENTS
 
Consolidated Statement of OperationsPhillips 66

Millions of Dollars Millions of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
2020  2019  2020  2019   2021 2020 2021 2020 
Revenues and Other IncomeRevenues and Other IncomeRevenues and Other Income
Sales and other operating revenuesSales and other operating revenues$10,913  27,847  31,791  50,950  Sales and other operating revenues$27,002 10,913 48,629 31,791 
Equity in earnings of affiliatesEquity in earnings of affiliates157  648  522  1,164  Equity in earnings of affiliates830 157 1,115 522 
Net gain on dispositionsNet gain on dispositions85  —  86   Net gain on dispositions2 85 2 86 
Other incomeOther income28  23  28  61  Other income51 28 66 28 
Total Revenues and Other IncomeTotal Revenues and Other Income11,183  28,518  32,427  52,176  Total Revenues and Other Income27,885 11,183 49,812 32,427 
Costs and ExpensesCosts and ExpensesCosts and Expenses
Purchased crude oil and productsPurchased crude oil and products9,608  24,554  28,048  45,609  Purchased crude oil and products25,218 9,608 45,283 28,048 
Operating expensesOperating expenses1,026  1,165  2,367  2,472  Operating expenses1,175 1,026 2,555 2,367 
Selling, general and administrative expensesSelling, general and administrative expenses409  408  728  774  Selling, general and administrative expenses433 409 841 728 
Depreciation and amortizationDepreciation and amortization343  334  685  665  Depreciation and amortization364 343 720 685 
ImpairmentsImpairments—   3,006   Impairments0 198 3,006 
Taxes other than income taxesTaxes other than income taxes114  97  271  225  Taxes other than income taxes119 114 258 271 
Accretion on discounted liabilitiesAccretion on discounted liabilities  11  11  Accretion on discounted liabilities6 12 11 
Interest and debt expenseInterest and debt expense117  115  228  234  Interest and debt expense143 117 289 228 
Foreign currency transaction losses   14  
Foreign currency transaction (gains) lossesForeign currency transaction (gains) losses(9)(9)
Total Costs and ExpensesTotal Costs and Expenses11,628  26,689  35,350  50,007  Total Costs and Expenses27,449 11,628 50,147 35,350 
Income (loss) before income taxesIncome (loss) before income taxes(445) 1,829  (2,923) 2,169  Income (loss) before income taxes436 (445)(335)(2,923)
Income tax expense (benefit)Income tax expense (benefit)(378) 325  (429) 395  Income tax expense (benefit)62 (378)(70)(429)
Net Income (Loss)Net Income (Loss)(67) 1,504  (2,494) 1,774  Net Income (Loss)374 (67)(265)(2,494)
Less: net income attributable to noncontrolling interestsLess: net income attributable to noncontrolling interests74  80  143  146  Less: net income attributable to noncontrolling interests78 74 93 143 
Net Income (Loss) Attributable to Phillips 66Net Income (Loss) Attributable to Phillips 66$(141) 1,424  (2,637) 1,628  Net Income (Loss) Attributable to Phillips 66$296 (141)(358)(2,637)
Net Income (Loss) Attributable to Phillips 66 Per Share of Common Stock (dollars)
Net Income (Loss) Attributable to Phillips 66 Per Share of Common Stock (dollars)
Net Income (Loss) Attributable to Phillips 66 Per Share of Common Stock (dollars)
BasicBasic$(0.33) 3.13  (6.00) 3.57  Basic$0.66 (0.33)(0.83)(6.00)
DilutedDiluted(0.33) 3.12  (6.00) 3.55  Diluted0.66 (0.33)(0.83)(6.00)
Weighted-Average Common Shares Outstanding (thousands)
Weighted-Average Common Shares Outstanding (thousands)
Weighted-Average Common Shares Outstanding (thousands)
BasicBasic438,756  453,681  440,050  455,630  Basic439,940 438,756 439,722 440,050 
DilutedDiluted438,756  455,585  440,050  457,620  Diluted440,396 438,756 439,722 440,050 
See Notes to Consolidated Financial Statements.See Notes to Consolidated Financial Statements.See Notes to Consolidated Financial Statements.
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Consolidated Statement of Comprehensive Income (Loss)Phillips 66
 
Millions of Dollars Millions of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
2020  2019  2020  2019   2021 2020 2021 2020 
Net Income (Loss)Net Income (Loss)$(67) 1,504  (2,494) 1,774  Net Income (Loss)$374 (67)(265)(2,494)
Other comprehensive income (loss)Other comprehensive income (loss)Other comprehensive income (loss)
Defined benefit plansDefined benefit plansDefined benefit plans
Actuarial loss arising during the period(300) —  (300) —  
Amortization to income of net actuarial loss, net prior service credit and settlements55  15  78  34  
Net actuarial gain (loss) arising during the periodNet actuarial gain (loss) arising during the period210 (300)210 (300)
Amortization of net actuarial loss, prior service credit and settlementsAmortization of net actuarial loss, prior service credit and settlements47 55 69 78 
Plans sponsored by equity affiliatesPlans sponsored by equity affiliates    Plans sponsored by equity affiliates23 29 
Income taxes on defined benefit plansIncome taxes on defined benefit plans59  (4) 54  (9) Income taxes on defined benefit plans(68)59 (74)54 
Defined benefit plans, net of income taxesDefined benefit plans, net of income taxes(183) 12  (163) 30  Defined benefit plans, net of income taxes212 (183)234 (163)
Foreign currency translation adjustmentsForeign currency translation adjustments26  (62) (196) (5) Foreign currency translation adjustments19 26 4 (196)
Income taxes on foreign currency translation adjustmentsIncome taxes on foreign currency translation adjustments—  (1)  (1) Income taxes on foreign currency translation adjustments0 0 
Foreign currency translation adjustments, net of income taxesForeign currency translation adjustments, net of income taxes26  (63) (195) (6) Foreign currency translation adjustments, net of income taxes19 26 4 (195)
Cash flow hedgesCash flow hedges—  (7) (9) (11) Cash flow hedges1 3 (9)
Income taxes on hedging activitiesIncome taxes on hedging activities—  —    Income taxes on hedging activities(1)(1)
Hedging activities, net of income taxesHedging activities, net of income taxes—  (7) (7) (10) Hedging activities, net of income taxes0 2 (7)
Other Comprehensive Income (Loss), Net of Income TaxesOther Comprehensive Income (Loss), Net of Income Taxes(157) (58) (365) 14  Other Comprehensive Income (Loss), Net of Income Taxes231 (157)240 (365)
Comprehensive Income (Loss)Comprehensive Income (Loss)(224) 1,446  (2,859) 1,788  Comprehensive Income (Loss)605 (224)(25)(2,859)
Less: comprehensive income attributable to noncontrolling interestsLess: comprehensive income attributable to noncontrolling interests74  80  143  146  Less: comprehensive income attributable to noncontrolling interests78 74 93 143 
Comprehensive Income (Loss) Attributable to Phillips 66Comprehensive Income (Loss) Attributable to Phillips 66$(298) 1,366  (3,002) 1,642  Comprehensive Income (Loss) Attributable to Phillips 66$527 (298)(118)(3,002)
See Notes to Consolidated Financial Statements.
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Consolidated Balance SheetPhillips 66
 
Millions of Dollars Millions of Dollars
June 30
2020
December 31
2019
June 30
2021
December 31
2020
AssetsAssetsAssets
Cash and cash equivalentsCash and cash equivalents$1,890  1,614  Cash and cash equivalents$2,207 2,514 
Accounts and notes receivable (net of allowances of $39 million in 2020 and $41 million in 2019)3,995  7,376  
Accounts and notes receivable (net of allowances of $46 million in 2021 and $37 million in 2020)Accounts and notes receivable (net of allowances of $46 million in 2021 and $37 million in 2020)6,627 5,688 
Accounts and notes receivable—related partiesAccounts and notes receivable—related parties857  1,134  Accounts and notes receivable—related parties1,435 834 
InventoriesInventories5,136  3,776  Inventories4,752 3,893 
Prepaid expenses and other current assetsPrepaid expenses and other current assets621  495  Prepaid expenses and other current assets759 347 
Total Current AssetsTotal Current Assets12,499  14,395  Total Current Assets15,780 13,276 
Investments and long-term receivablesInvestments and long-term receivables13,628  14,571  Investments and long-term receivables13,520 13,624 
Net properties, plants and equipmentNet properties, plants and equipment24,282  23,786  Net properties, plants and equipment23,688 23,716 
GoodwillGoodwill1,425  3,270  Goodwill1,425 1,425 
IntangiblesIntangibles874  869  Intangibles825 843 
Other assetsOther assets1,810  1,829  Other assets1,739 1,837 
Total AssetsTotal Assets$54,518  58,720  Total Assets$56,977 54,721 
LiabilitiesLiabilitiesLiabilities
Accounts payableAccounts payable$4,902  8,043  Accounts payable$8,066 5,171 
Accounts payable—related partiesAccounts payable—related parties466  532  Accounts payable—related parties879 378 
Short-term debtShort-term debt1,783  547  Short-term debt2,489 987 
Accrued income and other taxesAccrued income and other taxes1,046  979  Accrued income and other taxes1,362 1,351 
Employee benefit obligationsEmployee benefit obligations395  710  Employee benefit obligations412 573 
Other accrualsOther accruals1,431  835  Other accruals1,343 1,058 
Total Current LiabilitiesTotal Current Liabilities10,023  11,646  Total Current Liabilities14,551 9,518 
Long-term debtLong-term debt12,663  11,216  Long-term debt12,924 14,906 
Asset retirement obligations and accrued environmental costsAsset retirement obligations and accrued environmental costs625  638  Asset retirement obligations and accrued environmental costs694 657 
Deferred income taxesDeferred income taxes5,471  5,553  Deferred income taxes5,879 5,644 
Employee benefit obligationsEmployee benefit obligations1,360  1,044  Employee benefit obligations1,148 1,341 
Other liabilities and deferred creditsOther liabilities and deferred credits1,081  1,454  Other liabilities and deferred credits1,179 1,132 
Total LiabilitiesTotal Liabilities31,223  31,551  Total Liabilities36,375 33,198 
EquityEquityEquity
Common stock (2,500,000,000 shares authorized at $0.01 par value)
Issued (2020—648,468,487 shares; 2019—647,416,633 shares)
Common stock (2,500,000,000 shares authorized at $0.01 par value)
Issued (2021—649,761,235 shares; 2020—648,643,223 shares)
Common stock (2,500,000,000 shares authorized at $0.01 par value)
Issued (2021—649,761,235 shares; 2020—648,643,223 shares)
Par valuePar value  Par value6 
Capital in excess of parCapital in excess of par20,342  20,301  Capital in excess of par20,463 20,383 
Treasury stock (at cost: 2020—211,771,827 shares; 2019—206,390,806 shares)(17,116) (16,673) 
Treasury stock (at cost: 2021 and 2020—211,771,827 shares)Treasury stock (at cost: 2021 and 2020—211,771,827 shares)(17,116)(17,116)
Retained earningsRetained earnings18,631  22,064  Retained earnings15,345 16,500 
Accumulated other comprehensive lossAccumulated other comprehensive loss(1,148) (788) Accumulated other comprehensive loss(549)(789)
Total Stockholders’ EquityTotal Stockholders’ Equity20,715  24,910  Total Stockholders’ Equity18,149 18,984 
Noncontrolling interestsNoncontrolling interests2,580  2,259  Noncontrolling interests2,453 2,539 
Total EquityTotal Equity23,295  27,169  Total Equity20,602 21,523 
Total Liabilities and EquityTotal Liabilities and Equity$54,518  58,720  Total Liabilities and Equity$56,977 54,721 
See Notes to Consolidated Financial Statements.
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Consolidated Statement of Cash FlowsPhillips 66
Millions of Dollars Millions of Dollars
Six Months Ended
June 30
Six Months Ended
June 30
2020  2019   2021 2020 
Cash Flows From Operating ActivitiesCash Flows From Operating ActivitiesCash Flows From Operating Activities
Net income (loss)$(2,494) 1,774  
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Net lossNet loss$(265)(2,494)
Adjustments to reconcile net loss to net cash provided by operating activitiesAdjustments to reconcile net loss to net cash provided by operating activities
Depreciation and amortizationDepreciation and amortization685  665  Depreciation and amortization720 685 
ImpairmentsImpairments3,006   Impairments198 3,006 
Accretion on discounted liabilitiesAccretion on discounted liabilities11  11  Accretion on discounted liabilities12 11 
Deferred income taxesDeferred income taxes(21) 253  Deferred income taxes163 (21)
Undistributed equity earningsUndistributed equity earnings298  (44) Undistributed equity earnings(1)298 
Net gain on dispositionsNet gain on dispositions(86) (1) Net gain on dispositions(2)(86)
OtherOther (59) Other258 
Working capital adjustmentsWorking capital adjustmentsWorking capital adjustments
Accounts and notes receivableAccounts and notes receivable3,814  (534) Accounts and notes receivable(1,518)3,814 
InventoriesInventories(1,416) (1,549) Inventories(821)(1,416)
Prepaid expenses and other current assetsPrepaid expenses and other current assets(126) (182) Prepaid expenses and other current assets(413)(126)
Accounts payableAccounts payable(3,121) 1,368  Accounts payable3,482 (3,121)
Taxes and other accrualsTaxes and other accruals424  (253) Taxes and other accruals201 424 
Net Cash Provided by Operating ActivitiesNet Cash Provided by Operating Activities981  1,452  Net Cash Provided by Operating Activities2,014 981 
Cash Flows From Investing ActivitiesCash Flows From Investing ActivitiesCash Flows From Investing Activities
Capital expenditures and investmentsCapital expenditures and investments(1,862) (1,728) Capital expenditures and investments(711)(1,862)
Return of investments in equity affiliatesReturn of investments in equity affiliates88  35  Return of investments in equity affiliates158 88 
Proceeds from asset dispositionsProceeds from asset dispositions 83  Proceeds from asset dispositions24 
Advances/loans—related partiesAdvances/loans—related parties(231) (95) Advances/loans—related parties(245)(231)
Collection of advances/loans—related partiesCollection of advances/loans—related parties44  95  Collection of advances/loans—related parties0 44 
OtherOther(64) 24  Other(45)(64)
Net Cash Used in Investing ActivitiesNet Cash Used in Investing Activities(2,024) (1,586) Net Cash Used in Investing Activities(819)(2,024)
Cash Flows From Financing ActivitiesCash Flows From Financing ActivitiesCash Flows From Financing Activities
Issuance of debtIssuance of debt3,230  860  Issuance of debt465 3,230 
Repayment of debtRepayment of debt(541) (597) Repayment of debt(979)(541)
Issuance of common stockIssuance of common stock  Issuance of common stock24 
Repurchase of common stockRepurchase of common stock(443) (799) Repurchase of common stock0 (443)
Dividends paid on common stockDividends paid on common stock(789) (770) Dividends paid on common stock(788)(789)
Distributions to noncontrolling interestsDistributions to noncontrolling interests(127) (117) Distributions to noncontrolling interests(158)(127)
Net proceeds from issuance of Phillips 66 Partners LP common units 42  
Repurchase of noncontrolling interestsRepurchase of noncontrolling interests(24)
OtherOther(15) 301  Other(27)(13)
Net Cash Provided by (Used in) Financing ActivitiesNet Cash Provided by (Used in) Financing Activities1,323  (1,071) Net Cash Provided by (Used in) Financing Activities(1,487)1,323 
Effect of Exchange Rate Changes on Cash and Cash EquivalentsEffect of Exchange Rate Changes on Cash and Cash Equivalents(4)  Effect of Exchange Rate Changes on Cash and Cash Equivalents(15)(4)
Net Change in Cash and Cash EquivalentsNet Change in Cash and Cash Equivalents276  (1,200) Net Change in Cash and Cash Equivalents(307)276 
Cash and cash equivalents at beginning of periodCash and cash equivalents at beginning of period1,614  3,019  Cash and cash equivalents at beginning of period2,514 1,614 
Cash and Cash Equivalents at End of PeriodCash and Cash Equivalents at End of Period$1,890  1,819  Cash and Cash Equivalents at End of Period$2,207 1,890 
See Notes to Consolidated Financial Statements.

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Consolidated Statement of Changes in EquityPhillips 66

Millions of DollarsMillions of Dollars
Three Months Ended June 30Three Months Ended June 30
Attributable to Phillips 66  Attributable to Phillips 66 
Common Stock  
Par ValueCapital in Excess of ParTreasury StockRetained EarningsAccum. Other Comprehensive LossNoncontrolling InterestsTotal
March 31, 2021March 31, 2021$20,420 (17,116)15,449 (780)2,478 20,457 
Net incomeNet income   296  78 374 
Other comprehensive incomeOther comprehensive income    231  231 
Dividends paid on common stock ($0.90 per share)Dividends paid on common stock ($0.90 per share)   (394)  (394)
Benefit plan activityBenefit plan activity 43  (4)  39 
Distributions to noncontrolling interestsDistributions to noncontrolling interests     (82)(82)
Repurchase of noncontrolling interestsRepurchase of noncontrolling interests   (2) (21)(23)
June 30, 2021June 30, 2021$6 20,463 (17,116)15,345 (549)2,453 20,602 
Common Stock  
Par ValueCapital in Excess of ParTreasury StockRetained EarningsAccum. Other Comprehensive LossNoncontrolling InterestsTotal
March 31, 2020March 31, 2020$ 20,305  (17,116) 19,168  (991) 2,267  23,639  March 31, 2020$20,305 (17,116)19,168 (991)2,267 23,639 
Net income (loss)Net income (loss)—  —  —  (141) —  74  (67) Net income (loss)— — — (141)— 74 (67)
Other comprehensive lossOther comprehensive loss—  —  —  —  (157) —  (157) Other comprehensive loss— — — — (157)— (157)
Dividends paid on common stock ($0.90 per share)Dividends paid on common stock ($0.90 per share)—  —  —  (393) —  —  (393) Dividends paid on common stock ($0.90 per share)— — — (393)— — (393)
Benefit plan activityBenefit plan activity—  37  —  (3) —  —  34  Benefit plan activity— 37 — (3)— — 34 
Transfer of equity interestTransfer of equity interest—  —  —  —  —  305  305  Transfer of equity interest— — — — — 305 305 
Distributions to noncontrolling interestsDistributions to noncontrolling interests—  —  —  —  —  (66) (66) Distributions to noncontrolling interests— — — — — (66)(66)
June 30, 2020June 30, 2020$ 20,342  (17,116) 18,631  (1,148) 2,580  23,295  June 30, 2020$20,342 (17,116)18,631 (1,148)2,580 23,295 
March 31, 2019$ 19,879  (15,367) 20,408  (709) 2,528  26,745  
Net income—  —  —  1,424  —  80  1,504  
Other comprehensive loss—  —  —  —  (58) —  (58) 
Dividends paid on common stock ($0.90 per share)—  —  —  (406) —  —  (406) 
Repurchase of common stock—  —  (455) —  —  —  (455) 
Benefit plan activity—  30  —  (3) —  —  27  
Issuance of Phillips 66 Partners LP common units—   —  —  —   10  
Distributions to noncontrolling interests—  —  —  —  —  (61) (61) 
June 30, 2019$ 19,912  (15,822) 21,423  (767) 2,554  27,306  


Shares in Thousands
Three Months Ended June 30
 Common Stock IssuedTreasury Stock
March 31, 2020648,447  211,772  
Repurchase of common stock—  —  
Shares issued—share-based compensation21  —  
June 30, 2020648,468  211,772  
March 31, 2019646,716  193,165  
Repurchase of common stock—  5,122  
Shares issued—share-based compensation112  —  
June 30, 2019646,828  198,287  
See Notes to Consolidated Financial Statements.

Shares
Three Months Ended June 30
 Common Stock IssuedTreasury Stock
March 31, 2021649,638,881 211,771,827 
Repurchase of common stock 0 
Shares issued—share-based compensation122,354  
June 30, 2021649,761,235 211,771,827 
March 31, 2020648,446,534 211,771,827 
Repurchase of common stock— 
Shares issued—share-based compensation21,953 — 
June 30, 2020648,468,487 211,771,827 
See Notes to Consolidated Financial Statements.





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Consolidated Statement of Changes in EquityPhillips 66
Millions of Dollars
Six Months Ended June 30
Attributable to Phillips 66
Common Stock
Par ValueCapital in Excess of ParTreasury StockRetained EarningsAccum. Other Comprehensive LossNoncontrolling InterestsTotal
December 31, 2020$20,383 (17,116)16,500 (789)2,539 21,523 
Net income (loss)   (358) 93 (265)
Other comprehensive income    240  240 
Dividends paid on common stock ($1.80 per share)   (788)  (788)
Benefit plan activity 80  (7)  73 
Distributions to noncontrolling interests     (158)(158)
Repurchase of noncontrolling interests   (2) (21)(23)
June 30, 2021$6 20,463 (17,116)15,345 (549)2,453 20,602 
December 31, 2019$20,301 (16,673)22,064 (788)2,259 27,169 
Net income (loss)— — — (2,637)— 143 (2,494)
Other comprehensive loss— — — — (365)— (365)
Dividends paid on common stock ($1.80 per share)— — — (789)— — (789)
Repurchase of common stock— — (443)— — — (443)
Benefit plan activity— 41 — (5)— — 36 
Transfer of equity interest— — — — — 305 305 
Distributions to noncontrolling interests— — — — — (127)(127)
Other— — — (2)— 
June 30, 2020$20,342 (17,116)18,631 (1,148)2,580 23,295 

Millions of Dollars
Six Months Ended June 30, 2020
Attributable to Phillips 66
Common Stock
Par ValueCapital in Excess of ParTreasury StockRetained EarningsAccum. Other Comprehensive LossNoncontrolling InterestsTotal
December 31, 2019$ 20,301  (16,673) 22,064  (788) 2,259  27,169  
Net income (loss)—  —  —  (2,637) —  143  (2,494) 
Other comprehensive loss—  —  —  —  (365) —  (365) 
Dividends paid on common stock ($1.80 per share)—  —  —  (789) —  —  (789) 
Repurchase of common stock—  —  (443) —  —  —  (443) 
Benefit plan activity—  41  —  (5) —  —  36  
Transfer of equity interest—  —  —  —  —  305  305  
Distributions to noncontrolling interests—  —  —  —  —  (127) (127) 
Other—  —  —  (2)  —   
June 30, 2020$ 20,342  (17,116) 18,631  (1,148) 2,580  23,295  
December 31, 2018$ 19,873  (15,023) 20,489  (692) 2,500  27,153  
Cumulative effect of accounting changes—  —  —  81  (89) (1) (9) 
Net income—  —  —  1,628  —  146  1,774  
Other comprehensive income—  —  —  —  14  —  14  
Dividends paid on common stock ($1.70 per share)—  —  —  (770) —  —  (770) 
Repurchase of common stock—  —  (799) —  —  —  (799) 
Benefit plan activity—  34  —  (5) —  —  29  
Issuance of Phillips 66 Partners LP common units—   —  —  —  26  31  
Distributions to noncontrolling interests—  —  —  —  —  (117) (117) 
June 30, 2019$ 19,912  (15,822) 21,423  (767) 2,554  27,306  
Shares
Six Months Ended June 30
Common Stock IssuedTreasury Stock
December 31, 2020648,643,223 211,771,827 
Repurchase of common stock 0 
Shares issued—share-based compensation1,118,012  
June 30, 2021649,761,235 211,771,827 
December 31, 2019647,416,633 206,390,806 
Repurchase of common stock— 5,381,021 
Shares issued—share-based compensation1,051,854 — 
June 30, 2020648,468,487 211,771,827 
See Notes to Consolidated Financial Statements.

Shares in Thousands
Six Months Ended June 30
Common Stock IssuedTreasury Stock
December 31, 2019647,417  206,391  
Repurchase of common stock—  5,381  
Shares issued—share-based compensation1,051  —  
June 30, 2020648,468  211,772  
December 31, 2018645,692  189,526  
Repurchase of common stock—  8,761  
Shares issued—share-based compensation1,136  —  
June 30, 2019646,828  198,287  
See Notes to Consolidated Financial Statements.
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Notes to Consolidated Financial StatementsPhillips 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 20192020 Annual Report on Form 10-K. The results of operations for the three and six months ended June 30, 2020,2021, are not necessarily indicative of the results expected for the full year.


Note 2—Sales and Other Operating Revenues

Disaggregated Revenues
The following tables present our disaggregated sales and other operating revenues:

Millions of Dollars Millions of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
2020  2019  2020  2019   2021 2020 2021 2020 
Product Line and ServicesProduct Line and ServicesProduct Line and Services
Refined petroleum productsRefined petroleum products$8,701  22,922  24,858  41,715  Refined petroleum products$21,876 8,701 38,219 24,858 
Crude oil resalesCrude oil resales1,490  3,613  4,367  6,651  Crude oil resales3,204 1,490 6,393 4,367 
Natural gas liquids (NGL)Natural gas liquids (NGL)700  1,179  1,679  2,483  Natural gas liquids (NGL)1,943 700 3,717 1,679 
Services and other*
Services and other*
22  133  887  101  
Services and other*
(21)22 300 887 
Consolidated sales and other operating revenuesConsolidated sales and other operating revenues$10,913  27,847  31,791  50,950  Consolidated sales and other operating revenues$27,002 10,913 48,629 31,791 
Geographic Location**Geographic Location**Geographic Location**
United StatesUnited States$8,377  21,867  24,087  39,442  United States$21,297 8,377 37,909 24,087 
United KingdomUnited Kingdom972  2,512  3,281  4,943  United Kingdom2,835 972 5,122 3,281 
GermanyGermany613  1,092  1,471  2,049  Germany1,038 613 1,855 1,471 
Other foreign countriesOther foreign countries951  2,376  2,952  4,516  Other foreign countries1,832 951 3,743 2,952 
Consolidated sales and other operating revenuesConsolidated sales and other operating revenues$10,913  27,847  31,791  50,950  Consolidated sales and other operating revenues$27,002 10,913 48,629 31,791 
* Includes derivatives-related activities. See Note 12—Derivatives and Financial Instruments, for additional information.* Includes derivatives-related activities. See Note 12—Derivatives and Financial Instruments, for additional information.* Includes derivatives-related activities. See Note 12—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.** Sales and other operating revenues are attributable to countries based on the location of the operations generating the revenues.** Sales and other operating revenues are attributable to countries based on the location of the operations generating the revenues.



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Contract-Related Assets and Liabilities
At June 30, 2020,2021, and December 31, 2019,2020, receivables from contracts with customers were $3,237$5,948 million and $6,902$3,911 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 June 30, 2020,2021, and December 31, 2019,2020, our asset balances related to such payments were $376$426 million and $336$404 million, respectively.

Our contract liabilities represent advances from our customers prior to product or service delivery. At June 30, 2020,2021, and December 31, 2019,2020, contract liabilities were 0t material.immaterial.
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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 anthe unsatisfied performance obligation.obligations. We also have certain contracts in our Midstream segment that include minimum volume commitments with fixed pricing, which mostly expire by 2021.pricing. At June 30, 2020,2021, the remaining performance obligations related to these minimum volume commitment contracts were 0t material.immaterial.


Note 3—Credit Losses

We are exposed to credit losses primarily through our sales of refined petroleum products, crude oil and NGL. 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.

The negative economic impacts associated with Coronavirus Disease 2019 (COVID-19) increasehave increased the probability that certain of our counterparties may not be able to completely fulfill their obligations in a timely manner. In response, we have enhanced our credit monitoring, sought collateral to support some transactions, and required prepayments from higher-risk counterparties.

At June 30, 2020,2021, and December 31, 2019,2020, we reported $4,852$8,062 million and $8,510$6,522 million of accounts and notes receivable, net of allowances of $39$46 million and $41$37 million, respectively. Based on an aging analysis at June 30, 2020,2021, more than 99%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 standby letters of credit. See Note 10—Guarantees, and Note 11—Contingencies and Commitments, for more information on these off-balance sheet exposures.


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Note 4—Inventories

Inventories consisted of the following:

Millions of Dollars Millions of Dollars
June 30
2020
December 31
2019
June 30
2021
December 31
2020
Crude oil and petroleum productsCrude oil and petroleum products$4,806  3,452  Crude oil and petroleum products$4,365 3,536 
Materials and suppliesMaterials and supplies330  324  Materials and supplies387 357 
$5,136  3,776  $4,752 3,893 


Inventories valued on the last-in, first-out (LIFO) basis totaled $4,701$4,170 million and $3,331$3,368 million at June 30, 2020,2021, and December 31, 2019,2020, respectively. The estimated excess of current replacement cost over LIFO cost of inventories amounted to approximately $1.4$5.8 billion and $4.3$2.7 billion at June 30, 2020,2021, and December 31, 2019,2020, 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 inventory liquidations decreased our net income by $54 million in the second quarter of 2021, and increased our net loss by $82 million in the first six months of 2021. The impact was immaterial for the corresponding periods of 2020.


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Note 5—Investments, Loans and Long-Term Receivables

Equity Investments

DCP Midstream, LLC (DCP Midstream)
The fair value of our investment in DCP Midstream depends on the market value of DCP Midstream, LP (DCP Partners) common units. The market value of DCP Partners common units declined by approximately 85% in the first quarter of 2020.  As a result, at March 31, 2020, the fair value of our investment in DCP Midstream was significantly lower than its book value. We concluded the difference between its fair value and book value was not temporary primarily due to its magnitude. Accordingly, we recorded a $1.2 billion before-tax impairment of our investment in the first quarter of 2020. This charge is included in the “Impairments” line item on our consolidated statement of operations for the six months ended June 30, 2020. The impairment increased the basis difference for our investment in DCP Midstream to $1.8 billion at March 31, 2020, which indicated the carrying value of our investment was lower than our share of DCP Midstream’s recorded net assets at March 31, 2020. The basis difference is being amortized and recognized as a benefit to equity earnings over a period of 22 years, which was the estimated remaining useful life of DCP Midstream’s properties, plants and equipment (PP&E) at March 31, 2020. Equity earnings for the three and six months ended June 30, 2020, were increased by approximately $20 million and $30 million, respectively, due to the amortization of the basis difference. See Note 13—Fair Value Measurements, for additional information on the techniques used to determine the fair value of our investment in DCP Midstream. At June 30, 2020, our investment in DCP Midstream had a book value of $254 million.

Gray Oak Pipeline, LLC
Phillips 66 Partners LP (Phillips 66 Partners) has a consolidated holding company that owns 65% of Gray Oak Pipeline, LLC. Excluding a co-venturer’s 35% interest in the consolidated holding company, Phillips 66 Partners has an effective ownership interest of 42.25% in Gray Oak Pipeline, LLC. Gray Oak Pipeline, LLC has a third-party term loan facility with a borrowing capacity of $1,379 million, inclusive of accrued interest. Borrowings under the facility are due on June 3, 2022.  Phillips 66 Partners and its co-venturers provided a guarantee through an equity contribution agreement requiring proportionate equity contributions to Gray Oak Pipeline, LLC up to the total outstanding loan amount, plus any additional accrued interest and associated fees, if Gray Oak Pipeline, LLC defaults on certain of its obligations thereunder.  At June 30, 2020, the term loan facility was fully utilized by Gray Oak Pipeline, LLC, and Phillips 66 Partners’ 42.25% proportionate exposure under the equity contribution agreement was $583 million. 

During its development phase, Gray Oak Pipeline, LLC was considered a variable interest entity (VIE) because it did not have sufficient equity at risk to fully fund the construction of all assets required for principal operations. We determined we were not the primary beneficiary because we and our co-venturers jointly directed the activities of Gray Oak Pipeline, LLC that most significantly impacted economic performance. The Gray Oak Pipeline commenced full operations in the second quarter of 2020 and ceased being a VIE. At June 30, 2020, Phillips 66 Partners’ investment in the Gray Oak Pipeline had a book value of $896 million. See Note 19—Phillips 66 Partners LP, for additional information regarding Phillips 66 Partners’ ownership in Gray Oak Pipeline, LLC.


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Dakota Access, LLC (Dakota Access) and Energy Transfer Crude Oil Company, LLC (ETCO)
In March 2019, a wholly owned subsidiary of2020, the trial court presiding over litigation regarding the Dakota Access closedPipeline ordered the U.S. Army Corps of Engineers (USACE) to prepare an offering of $2.5 billion aggregate principal amount of unsecured senior notes, consisting of:

$650 million aggregate principal amount of 3.625% Senior Notes dueEnvironmental Impact Statement (EIS) relating to an easement under Lake Oahe in North Dakota and later vacated the easement. Although the easement has been vacated, the USACE has indicated that it will not take action to stop pipeline operations while it proceeds with the EIS, which is expected to be completed in 2022.
$1.0 billion aggregate principal amount of 3.900% Senior Notes due 2024.
$850 million aggregate principal amount of 4.625% Senior Notes due 2029. In May 2021, the court denied a request for an injunction to shut down the pipeline while the EIS is being prepared and in June 2021, dismissed the litigation. It is possible that the litigation could be reopened or new litigation challenging the EIS, once completed, could be filed.

Dakota Access and ETCO have guaranteed repayment of the notes.$2.5 billion aggregate principal amount of senior unsecured notes issued by a wholly owned subsidiary of Dakota Access. In addition, Phillips 66 Partners LP (Phillips 66 Partners) and its co-venturers in Dakota Access 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 ongoing litigation related to an easement granted by the U.S. Army Corps of Engineers (USACE) to allow the pipeline to be constructed under Lake Oahe in North Dakota. Contributions may be required if Dakota Access determines that the issues included in any such final judgment cannot be remediated and Dakota Access has or is projected to have insufficient funds to satisfy repayment of the notes. If Dakota Access undertakes remediation to cure issues raised in a final judgment, contributions may be required if any series of the notes become due, whether by acceleration or at maturity, during such time,certain circumstances relating to the extent Dakota Access has or is projected to have insufficient funds to pay such amounts.litigation described above. At June 30, 2020,2021, Phillips 66 Partners’ share of the maximum potential equity contributions under the CECU was approximately $631 million.

In March 2020, the court presiding over this litigation ordered the USACE to prepare an Environmental Impact Statement (EIS), and requested additional information to enable a decision on whether the Dakota Access Pipeline should be shut down while the EIS is being prepared. On July 6, 2020, the court ordered the Dakota Access Pipeline to be shut down and emptied of crude oil by August 5, 2020, and that the pipeline should remain shut down pending the preparation of the EIS by the USACE, which the USACE has indicated is expected to take approximately 13 months. Dakota Access filed an appeal and a request for a stay of the order. On July 14, 2020, an appeals court granted a temporary stay of the lower court’s order directing the pipeline to be shut down and emptied of crude oil. The appeals court has not yet ruled on the motion for a stay during the appeals process. In addition to the potential obligations under the CECU, ifIf the pipeline is required to cease operations, pending the preparation of the EIS, and should Dakota Access and ETCO not have sufficient funds to pay ongoing expenses, Phillips 66 Partners also could be askedrequired to support its share of the ongoing expenses, including scheduled interest payments on the notes of approximately $25 million annually.annually, in addition to the potential obligations under the CECU.

At June 30, 2021, the aggregate book value of Phillips 66 Partners’ investments in Dakota Access and ETCO was $577 million.

CF United LLC (CF United)
We hold a 50% voting interest and a 48% economic interest in CF United, a retail marketing joint venture with operations primarily on the U.S. West Coast. CF United is considered a VIEvariable interest entity (VIE) because our co-venturer has an option to sellrequire us to purchase its interest to us based on a fixed multiple. The put option becomes effective July 1, 2023, and expires on March 31, 2024. The put option is viewed as a variable interest as the purchase price on the exercise date may not represent the then-current fair value of CF United. We have determined that we are not the primary beneficiary because we and our co-venturer jointly direct the activities of CF United that most significantly impact economic performance. At June 30, 2020,2021, our maximum exposure to loss was comprised of our $322$267 million investment in CF United, and any potential future loss resulting from the put option ifshould the purchase price based on a fixed multiple exceedsexceed the then-current fair value of CF United.

Liberty Pipeline LLC (Liberty)
Liberty is a 50 percent-owned joint venture formed to develop and construct the Liberty Pipeline system which, upon completion, will transport crude oil from the Rockies and Bakken production areas to Cushing, Oklahoma. Liberty is considered a VIE because it does not have sufficient equity at risk to fully fund the construction of all assets required for principal operations. We have determined we are not the primary beneficiary because we and our co-venturer jointly direct the activities of Liberty that most significantly impact economic performance. On March 2, 2020, Phillips 66 Partners closed a transaction to acquire our 50% interest in Liberty for $75 million. The development and construction of the Liberty Pipeline system have been deferred as a result of the current challenging business environment. At June 30, 2020, our maximum exposure to loss was $251 million, which represented the book value of Phillips 66 Partners’ investment in Liberty of $202 million and our outstanding proportionate vendor guarantees of $49 million.



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Red Oak Pipeline LLC (Red Oak)
We hold a 50% interest in a joint venture formed to develop and construct the Red Oak Pipeline system which, upon completion, will transport crude oil from Cushing, Oklahoma, and the Permian to multiple destinations along the Texas Gulf Coast, including Corpus Christi, Ingleside, Houston, and Beaumont, Texas. Red Oak is considered a VIE because it does not have sufficient equity at risk to fully fund the construction of all assets required for principal operations. We have determined we are not the primary beneficiary because we and our co-venturer jointly direct the activities of Red Oak that most significantly impact economic performance. The development and construction of the Red Oak Pipeline system have been deferred as a result of the current challenging business environment. In June 2020, Red Oak fully repaid its outstanding member loan. At June 30, 2020, our maximum exposure to loss was the book value of our investment in Red Oak of $104 million.

OnCue Holdings, LLC (OnCue)
We hold a 50% interest in OnCue, a joint venture that owns and operates retail convenience stores. We fully guaranteed various debt agreements of OnCue and our co-venturer did not participate in the guarantees. This entity is considered a VIE because our debt guarantees resulted in OnCue not being exposed to all potential losses. We have determined we are not the primary beneficiary because we do not have the power to direct the activities that most significantly impact OnCue’s economic performance. At June 30, 2020,2021, our maximum exposure to loss was $155$184 million, which represented the book value of our investment in OnCue of $86$106 million and guaranteed debt obligations of $69$78 million.

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Liberty Pipeline LLC (Liberty)
In the first quarter of 2021, Phillips 66 Partners’ decision to exit the Liberty Pipeline project resulted in a $198 million before-tax impairment of its investment in Liberty. The impairment is included in the “Impairments” line item on our consolidated statement of operations for the six months ended June 30, 2021. See Note 7—Impairments, and Note 13—Fair Value Measurements, for additional information regarding the impairment and the techniques used to determine the fair value of Phillips 66 Partners’ investment in Liberty. In April 2021, Phillips 66 Partners transferred its ownership interest in Liberty to its co-venturer for cash and certain pipeline assets with a value that approximated its book value of $46 million at March 31, 2021.

Related Party Loans
We and our co-venturer provided member loans to WRB Refining LP (WRB). At June 30, 2021, our 50% share of the outstanding member loan balance, including accrued interest, was $525 million.


Note 6—Properties, Plants and Equipment

Our gross investment in PP&Eproperties, plants and equipment (PP&E) and the associated accumulated depreciation and amortization (Accum. D&A) balances were as follows:

 Millions of Dollars
 June 30, 2020December 31, 2019
 Gross
PP&E
Accum.
D&A
  Net
PP&E
Gross
PP&E
Accum.
D&A
Net
PP&E
Midstream$11,931  2,543  9,388  11,221  2,391  8,830  
Chemicals—  —  —  —  —  —  
Refining24,110  10,730  13,380  23,692  10,336  13,356  
Marketing and Specialties (M&S)1,695  945  750  1,847  959  888  
Corporate and Other1,401  637  764  1,311  599  712  
$39,137  14,855  24,282  38,071  14,285  23,786  
















 Millions of Dollars
 June 30, 2021December 31, 2020
 Gross
PP&E
Accum.
D&A
  Net
PP&E
Gross
PP&E
Accum.
D&A
Net
PP&E
Midstream$12,289 2,885 9,404 12,313 2,815 9,498 
Chemicals0 0 0 
Refining25,293 12,569 12,724 24,647 12,019 12,628 
Marketing and Specialties1,805 1,023 782 1,815 1,007 808 
Corporate and Other1,485 707 778 1,448 666 782 
$40,872 17,184 23,688 40,223 16,507 23,716 


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Note 7—GoodwillImpairments

Millions of Dollars
 Three Months Ended
June 30
Six Months Ended
June 30
 2021202020212020
Midstream$0 198 1,161 
Refining0 0 1,845 
Total impairments$0 198 3,006 


Equity Investments

Liberty
In the first quarter of 2021, Phillips 66 Partners decided to exit the Liberty Pipeline project, which had previously been deferred due to the challenging business environment caused by the COVID-19 pandemic. As a result, Phillips 66 Partners recorded a $198 million before-tax impairment to reduce the book value of its investment in Liberty at March 31, 2021, to estimated fair value.

DCP Midstream, LLC (DCP Midstream)
In the first quarter of 2020, the market value of DCP Partners, LP (DCP Partners) common units declined by approximately 85%. As a result, at March 31, 2020, the fair value of our investment in DCP Midstream was significantly lower than its book value. We concluded this difference was not temporary primarily due to its magnitude, and we recorded a $1,161 million before-tax impairment of our investment in the first quarter of 2020.

Goodwill
Our stock price declined significantly in the first quarter of 2020, mainly due to the volatilitydisruption in global commodity and equity markets related to the COVID-19 pandemic and other factors.pandemic. We assessed our goodwill for impairment due to the decline in our market capitalization and concluded that the carrying value of our Refining reporting unit at March 31, 2020, was greater than its fair value by an amount in excess of its goodwill balance. Accordingly, we recorded a before-tax goodwill impairment charge of $1,845 million in our Refining segment during the first quarter of 2020. This charge is

These impairment charges are included inwithin the “Impairments” line item on our consolidated statement of operations for the six months ended June 30, 2020.operations. See Note 13—Fair Value Measurements, for additional information on the techniquesdetermination of fair value used to determine the fair value of our Refining reporting unit.record these impairments.

Outlook
The carrying amountCOVID-19 pandemic continues to disrupt economic activities globally. Reduced demand for refined petroleum products resulted in low refining margins and decreased volumes through refineries and logistics infrastructure in 2020. Since the beginning of goodwill2021, demand for refined petroleum products has started to recover following the administration of COVID-19 vaccines and the easing of pandemic restrictions. Consequently, refining margins have improved, as has volume throughput. However, refining profitability remains challenged. The depth and duration of the economic consequences of the COVID-19 pandemic remain uncertain and we continue to monitor our asset and investment portfolio. The consequences of the sustained disruption of economic activities by segment at June 30, 2020 was:the pandemic may include additional asset impairments and portfolio rationalization in the future.

 Millions of Dollars
 MidstreamRefiningM&STotal
Balance at January 1, 2020$626  1,845  799  3,270  
Impairments—  (1,845) —  (1,845) 
Balance at June 30, 2020$626  —  799  1,425  


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Note 8—Earnings (Loss) Per Share

The numerator of basic earnings (loss) per share (EPS) is net income (loss) attributable to Phillips 66, adjusted for noncancelable dividends paid on unvested share-based employee awards during the vesting period (participating securities). and the premium paid for the repurchase of noncontrolling interests. 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 (loss) attributable to Phillips 66, which is reduced only by dividend equivalents paid on participating securities for which the dividends are more dilutive than the participation of the awards in the earnings (losses)(loss) of the periods presented.presented, and the premium paid for the repurchase of noncontrolling interests. 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
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
2020201920202019 2021202020212020
BasicDilutedBasicDilutedBasicDilutedBasicDilutedBasicDilutedBasicDilutedBasicDilutedBasicDiluted
Amounts Attributed to Phillips 66 Common Stockholders (millions):
Amounts Attributed to Phillips 66 Common Stockholders (millions):
Amounts Attributed to Phillips 66 Common Stockholders (millions):
Net income (loss) attributable to Phillips 66Net income (loss) attributable to Phillips 66$(141) (141) 1,424  1,424  (2,637) (2,637) 1,628  1,628  Net income (loss) attributable to Phillips 66$296 296 (141)(141)(358)(358)(2,637)(2,637)
Income allocated to participating securitiesIncome allocated to participating securities(2) (2) (2) (1) (4) (4) (3) (2) Income allocated to participating securities(3)(3)(2)(2)(6)(6)(4)(4)
Premium paid for the repurchase of noncontrolling interestsPremium paid for the repurchase of noncontrolling interests(2)(2)(2)(2)
Net income (loss) available to common stockholdersNet income (loss) available to common stockholders$(143) (143) 1,422  1,423  (2,641) (2,641) 1,625  1,626  Net income (loss) available to common stockholders$291 291 (143)(143)(366)(366)(2,641)(2,641)
Weighted-average common shares outstanding (thousands):
Weighted-average common shares outstanding (thousands):
436,688  438,756  451,216  453,681  437,851  440,050  453,041  455,630  
Weighted-average common shares outstanding (thousands):
437,909 439,940 436,688 438,756 437,639 439,722 437,851 440,050 
Effect of share-based compensationEffect of share-based compensation2,068  —  2,465  1,904  2,199  —  2,589  1,990  Effect of share-based compensation2,031 456 2,068 2,083 0 2,199 
Weighted-average common shares
outstanding—EPS
Weighted-average common shares
outstanding—EPS
438,756  438,756  453,681  455,585  440,050  440,050  455,630  457,620  Weighted-average common shares
outstanding—EPS
439,940 440,396 438,756 438,756 439,722 439,722 440,050 440,050 
Earnings (Loss) Per Share of Common Stock (dollars)
Earnings (Loss) Per Share of Common Stock (dollars)
$(0.33) (0.33) 3.13  3.12  (6.00) (6.00) 3.57  3.55  
Earnings (Loss) Per Share of Common Stock (dollars)
$0.66 0.66 (0.33)(0.33)(0.83)(0.83)(6.00)(6.00)


Note 9—Debt

2021 Debt Issuances and Repayments
At June 30, 2021, borrowings of $15 million were outstanding and $1 million in letters of credit had been drawn under Phillips 66 Partners’ $750 million revolving credit facility, compared with outstanding borrowings of $415 million and $1 million in letters of credit drawn under the facility at December 31, 2020.

In April 2021, Phillips 66 Partners entered into a $450 million term loan agreement and borrowed the full amount. The term loan agreement has a maturity date of April 5, 2022, and the outstanding borrowings can be repaid at any time and from time to time, in whole or in part, without premium or penalty. Borrowings bear interest at a floating rate based on either a Eurodollar rate or a reference rate, plus a margin of 0.875%. Proceeds were primarily used to repay amounts borrowed under Phillips 66 Partners’ $750 million revolving credit facility.

In April 2021, Phillips 66 Partners repaid $50 million of its tax-exempt bonds upon maturity.

In February 2021, Phillips 66 repaid $500 million outstanding principal balance of its floating-rate senior notes due February 2021.


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Note 9—2020 Debt Issuances and Repayments

Debt IssuancesSenior Unsecured Notes
On June 10, 2020, Phillips 66 closed its public offering of $1 billion aggregate principal amount of senior unsecured notes consisting of:

$150 million aggregate principal amount of 3.850% Senior Notes due 2025.
$850 million aggregate principal amount of 2.150% Senior Notes due 2030.

On April 9, 2020, Phillips 66 closed its public offering of $1 billion aggregate principal amount of senior unsecured notes consisting of:

$500 million aggregate principal amount of 3.700% Senior Notes due 2023.
$500 million aggregate principal amount of 3.850% Senior Notes due 2025.

Interest on the Senior Notes due 2023 is payable semiannually on April 6 and October 6 of each year, commencing on October 6, 2020. The Senior Notes due 2025 issued on June 10, 2020, constitute a further issuance of the Senior Notes due 2025 originally issued on April 9, 2020. The $650 million in aggregate principal amount of Senior Notes due 2025 is treated as a single class of debt securities. Interest on the Senior Notes due 2025 is payable semiannually on April 9 and October 9 of each year, commencing on October 9, 2020. Interest on the Senior Notes due 2030 is payable semiannually on June 15 and December 15 of each year, commencing on December 15, 2020.

Proceeds received from the public offerings of senior unsecured notes on June 10, 2020, and April 9, 2020, were $1,008 million exclusive of accrued interest received, and $993 million, respectively, net of underwriters’ discounts or premiums and commissions, as well as debt issuance costs. These proceeds are beingwere used for general corporate purposes.

Term Loan Facility
On March 19, 2020, Phillips 66 entered into a $1 billion 364-day delayed draw term loan agreement (the Facility) and borrowed $1 billion under the Facility shortly thereafter. On April 6, 2020, Phillips 66 increased the size of the Facility to $2 billion, with $1 billion of capacity remaining undrawn at June 30, 2020. Inand in June 2020, the Facility was amended to extend the commitment period to September 19, 2020. We did not draw additional amounts under the Facility before the end of the commitment period or further extend the commitment period. In November 2020, we repaid $500 million of borrowings outstanding under the Facility, and the Facility was amended to extend the maturity date of the remaining $500 million outstanding borrowings from March 18, 2021, to November 20, 2023. Borrowings under the Facility bear interest at a floating rate based on either thea Eurodollar rate or thea reference rate, plus a margin determined by the credit rating of Phillips 66’s senior unsecured long-term debt. Phillips 66 is usingused the proceeds from the debt issuance for general corporate purposes.

At June 30, 2020, borrowings of $215 million were outstanding and $3 million in letters of credit had been drawn under Phillips 66 Partners’ $750 million revolving credit facility.

Other Debt Repayments
In April 2020, Phillips 66 repaid the $300 million outstanding principal balance of its floating-rate notes due April 2020 and the $200 million outstanding principal balance of its term loan facility due April 2020. Also in April 2020, Phillips 66 Partners repaid the $25 million outstanding principal balance of its tax-exempt bonds due April 2020.

upon maturity.


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Note 10—Guarantees

At June 30, 2020,2021, 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 onfor our headquarters facility in Houston, Texas, we have a residual value guarantee with a maximum future exposure of $554 million at June 30, 2020. The operating lease term ends in June 2021 and provides us 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 June 30, 2021. We also have residual value guarantees associated with railcar and airplane leases with maximum potential future paymentsexposures totaling $351$209 million. These leases have remaining terms of up to fournine years.

Guarantees of Joint Venture and Other Obligations
In June 2019, Phillips 66 Partners issued a guarantee through an equity contribution agreement for 42.25% of Gray Oak Pipeline, LLC’s third-party term loan facility. See Note 5—Investments, Loans and Long-Term Receivables, for additional information on Gray Oak Pipeline, LLC.

In March 2019, Phillips 66 Partners and its co-venturers in Dakota Access provided a CECU in conjunction with ana senior unsecured senior notes offering. See Note 5—Investments, Loans and Long-Term Receivables, for additional information on Dakota Access and the CECU.

In addition, atAt June 30, 2020,2021, we also had other guarantees outstanding primarily for our portion of certain joint venture debt, obligations and purchase obligations, which have remaining terms of up to eightseven years. The maximum potential amount of future payments to third partiesexposures under these guarantees waswere approximately $155$148 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 indemnification. Agreements associated with these sales include indemnifications for taxes, litigation, environmental liabilities, permits and licenses, and employee claims, as well asand real estate indemnity against 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 June 30, 2020,2021, and December 31, 2019,2020, the carrying amount of recorded indemnifications was $154$149 million and $153$145 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 June 30, 2020,2021, and December 31, 2019,2020, environmental accruals for known contamination of $107$108 million and $105$104 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 11—Contingencies and Commitments.

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Indemnification and Release Agreement
In 2012, in connection with our separation from ConocoPhillips, we entered into thean 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-indemnitiescross 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 11—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 less than certain.uncertain.

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 U.S. Environmental Protection Agency (EPA)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 atfor 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.

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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 June 30, 2020,2021, our total environmental accruals were $429$455 million, compared with $441$427 million at December 31, 2019.2020. 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.

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 June 30, 2020,2021, we had performance obligations secured by letters of credit and bank guarantees of $461$883 million related to various purchase and other commitments incident to the ordinary conduct of business.


Note 12—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 operations. 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 operations. Cash flows from all our 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 feedstock, 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 13—Fair Value Measurements.

Commodity Derivative Contracts—We sell into or receive supply from the worldwide crude oil, refined petroleum product, NGL, natural gas, renewable feedstock, 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 Millions of Dollars
June 30, 2020December 31, 2019 June 30, 2021December 31, 2020
Commodity DerivativesEffect of Collateral NettingNet Carrying Value Presented on the Balance SheetCommodity DerivativesEffect of Collateral NettingNet Carrying Value Presented on the Balance SheetCommodity DerivativesEffect of Collateral NettingNet Carrying Value Presented on the Balance SheetCommodity DerivativesEffect of Collateral NettingNet Carrying Value Presented on the Balance Sheet
AssetsLiabilitiesAssetsLiabilities Effect of Collateral NettingNet Carrying Value Presented on the Balance SheetAssetsNet Carrying Value Presented on the Balance Sheet
AssetsAssetsAssets
Prepaid expenses and other current assetsPrepaid expenses and other current assets$56  (25) —  31  23  —  —  23  Prepaid expenses and other current assets$18 0 0 18 13 13 
Other assetsOther assets—  —  —  —   —  —   Other assets6 (1)0 5 (4)
LiabilitiesLiabilitiesLiabilities
Other accrualsOther accruals1,216  (1,399) 168  (15) 1,188  (1,281) 80  (13) Other accruals1,703 (1,886)152 (31)665 (721)46 (10)
Other liabilities and deferred creditsOther liabilities and deferred credits—  (1) —  (1) —  (1) —  (1) Other liabilities and deferred credits0 (1)0 (1)
TotalTotal$1,272  (1,425) 168  15  1,214  (1,282) 80  12  Total$1,727 (1,888)152 (9)683 (725)46 

At June 30, 2020,2021, and December 31, 2019,2020, 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 operations, were:
 
Millions of Dollars Millions of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
2020  2019  2020  2019   2021 2020 2021 2020 
Sales and other operating revenuesSales and other operating revenues$(180) 17  499  (160) Sales and other operating revenues$(193)(180)(316)499 
Other incomeOther income —   13  Other income18 19 
Purchased crude oil and productsPurchased crude oil and products(124) 54  317  (101) Purchased crude oil and products(213)(124)(348)317 
Net gain (loss) from commodity derivative activityNet gain (loss) from commodity derivative activity$(298) 71  825  (248) Net gain (loss) from commodity derivative activity$(388)(298)(645)825 


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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 at least 98%more than 95% at June 30, 2020,2021, and December 31, 2019.2020.

 Open Position
Long / (Short)
 June 30
2020
December 31
2019
Commodity
Crude oil, refined petroleum products and NGL (millions of barrels)
(36) (16) 

 Open Position
Long / (Short)
 June 30
2021
December 31
2020
Commodity
Crude oil, refined petroleum products, NGL and renewable feedstocks (millions of barrels)
(35)(13)

Interest Rate Derivative Contracts—In 2016, we entered into interest rate swaps to hedge the variability of lease payments on our headquarters facility. These monthly lease payments vary based on monthly changes in the one-month London Inter-BankInterbank Offered Rate (LIBOR) and changes, if any, in our credit rating over the five-year term of the lease.rating. The pay-fixed, receive-floating interest rate swaps have an aggregate notional value of $650 million and endended in April 2021. We haveThese swaps were designated these swaps as cash flow hedges.

The aggregate net fair value of these swaps was immaterial at June 30, 2020, and December 31, 2019. We reportreported the mark-to-market gains or losses on our interest rate swaps designated as highly effective cash flow hedges as a component of other comprehensive income (loss), and reclassifyreclassified such gains and losses into earnings (loss) in the same period during which the hedged transaction affects earnings.affected earnings (loss). Net realized gains and losses from settlements of the swaps were immaterial for the three and six months ended June 30, 20202021 and 2019.2020.

We currently estimate that before-tax losses of $7 million will be reclassified from accumulated other comprehensive loss into general and administrative expenses during the next 12 months as the hedged transactions settle; however, the actual amounts that will be reclassified will vary based on changes in interest rates.

Credit Risk from Derivative Instruments
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 rating. 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 June 30, 2020,2021, and December 31, 2019.2020.


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Note 13—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—We fair value our exchange-traded contracts based on quoted market prices obtained from the New York Mercantile Exchange, the Intercontinental Exchange or other exchanges, and classify them 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.
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.
We determine the fair value of our 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.
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.
Debt—The carrying amount of our floating-rate debt approximates fair value. The fair value of our fixed-rate debt is estimated based on observable market prices.

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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 Millions of Dollars
June 30, 2020 June 30, 2021
Fair Value HierarchyTotal Fair Value of Gross Assets & LiabilitiesEffect of Counterparty NettingEffect of Collateral NettingDifference in Carrying Value and Fair ValueNet Carrying Value Presented on the Balance SheetFair Value HierarchyTotal Fair Value of Gross Assets & LiabilitiesEffect of Counterparty NettingEffect of Collateral NettingDifference in Carrying Value and Fair ValueNet Carrying Value Presented on the Balance Sheet
Level 1Level 2Level 3 Level 1Level 2Difference in Carrying Value and Fair ValueNet Carrying Value Presented on the Balance Sheet
Commodity Derivative AssetsCommodity Derivative AssetsCommodity Derivative Assets
Exchange-cleared instrumentsExchange-cleared instruments$850  392  —  1,242  (1,241) —  —   Exchange-cleared instruments$878 832 0 1,710 (1,704)0 0 6 
Physical forward contractsPhysical forward contracts—  30  —  30  —  —  —  30  Physical forward contracts0 17 0 17 0 0 0 17 
Rabbi trust assetsRabbi trust assets129  —  —  129  N/A—  129  Rabbi trust assets155 0 0 155 N/A0 155 
$979  422  —  1,401  (1,241) —  —  160  $1,033 849 0 1,882 (1,704)0 0 178 
Commodity Derivative LiabilitiesCommodity Derivative LiabilitiesCommodity Derivative Liabilities
Exchange-cleared instrumentsExchange-cleared instruments$986  424  —  1,410  (1,241) (168) —   Exchange-cleared instruments$1,040 816 0 1,856 (1,704)(152)0 0 
Physical forward contractsPhysical forward contracts—  14   15  —  —  —  15  Physical forward contracts0 32 0 32 0 0 0 32 
Interest rate derivatives—   —   —  —  —   
Floating-rate debtFloating-rate debt—  1,787  —  1,787  N/A—  1,787  Floating-rate debt0 1,440 0 1,440 N/A0 1,440 
Fixed-rate debt, excluding finance leasesFixed-rate debt, excluding finance leases—  14,023  —  14,023  N/A(1,643) 12,380  Fixed-rate debt, excluding finance leases0 15,546 0 15,546 N/A(1,870)13,676 
$986  16,255   17,242  (1,241) (168) (1,643) 14,190  $1,040 17,834 0 18,874 (1,704)(152)(1,870)15,148 



Millions of Dollars Millions of Dollars
December 31, 2019 December 31, 2020
Fair Value HierarchyTotal Fair Value of Gross Assets & LiabilitiesEffect of Counterparty NettingEffect of Collateral NettingDifference in Carrying Value and Fair ValueNet Carrying Value Presented on the Balance SheetFair Value HierarchyTotal Fair Value of Gross Assets & LiabilitiesEffect of Counterparty NettingEffect of Collateral NettingDifference in Carrying Value and Fair ValueNet Carrying Value Presented on the Balance Sheet
Level 1Level 2Level 3 Level 1Level 2Level 3Net Carrying Value Presented on the Balance Sheet
Commodity Derivative AssetsCommodity Derivative AssetsCommodity Derivative Assets
Exchange-cleared instrumentsExchange-cleared instruments$820  368  —  1,188  (1,188) —  —  —  Exchange-cleared instruments$314 356 670 (669)
Physical forward contractsPhysical forward contracts—  26  —  26  —  —  —  26  Physical forward contracts13 13 13 
Interest rate derivatives—   —   —  —  —   
Rabbi trust assetsRabbi trust assets127  —  —  127  N/A—  127  Rabbi trust assets143 143 N/A143 
$947  395  —  1,342  (1,188) —  —  154  $457 369 826 (669)157 
Commodity Derivative LiabilitiesCommodity Derivative LiabilitiesCommodity Derivative Liabilities
Exchange-cleared instrumentsExchange-cleared instruments$884  385  —  1,269  (1,188) (80) —   Exchange-cleared instruments$351 364 715 (669)(46)
OTC instruments—   —   —  —  —   
Physical forward contractsPhysical forward contracts—  12  —  12  —  —  —  12  Physical forward contracts10 10 10 
Interest-rate derivativesInterest-rate derivatives
Floating-rate debtFloating-rate debt—  1,100  —  1,100  N/A—  1,100  Floating-rate debt1,940 1,940 N/A1,940 
Fixed-rate debt, excluding finance leasesFixed-rate debt, excluding finance leases—  11,813  —  11,813  N/A(1,438) 10,375  Fixed-rate debt, excluding finance leases15,597 15,597 N/A(1,927)13,670 
$884  13,311  —  14,195  (1,188) (80) (1,438) 11,489  $351 17,914 18,265 (669)(46)(1,927)15,623 


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The rabbi trust assets 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. See Note 12—Derivatives and Financial Instruments, for information regarding where the assets and liabilities related to our commodity and interest rate derivatives are recorded on our consolidated balance sheet.

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Nonrecurring Fair Value Measurements
The
Equity Investments
In the first quarter of 2021, Phillips 66 Partners wrote down the book value of its investment in Liberty to estimated fair value using a Level 3 nonrecurring fair value measurement. This nonrecurring measurement was based on the estimated fair value of Phillip 66 Partners’ share of the joint venture’s pipeline assets and net working capital. See Note 5—Investments, Loans and Long-Term Receivables, for more information regarding Phillips 66 Partners’ transfer of its ownership in Liberty to its co-venturer in April 2021.

In the first quarter of 2020, the nonrecurring fair value measurement used to record an impairment of our DCP Midstream investment at March 31, 2020, was the fair value of our share of DCP Midstream’s limited partner interest in DCP Partners, which was estimated based on average market prices of DCP Partners common units for a 15-daymulti-day trading period encompassing March 31, 2020. This valuation resulted in a Level 2 nonrecurring fair value measurement. See Note 5—Investments, Loans and Long-Term Receivables, for additional information on the impairment.

Goodwill
The carrying value of the Refining reporting unit’s goodwill was remeasured to fair value on a nonrecurring basis in the first quarter of 2020.  The fair value of the Refining reporting unit was calculated by weighting the results from the income approach and the market approach.  The income approach usesused a discounted cash flow model that requiresincluded various observable and nonobservable inputs, such as prices, volumes, expenses, capital expenditures, discount rates and projected long-term growth rates and terminal values. The market approach usesused peer company enterprise values relative to current and future net income (loss) before net interest expense, income taxes, depreciation and amortization (EBITDA) projections to arrive at an average multiple.  This multiple was applied to the reporting unit’s current and projected EBITDA, with consideration for an estimated market participant acquisition premium.  The resulting Level 3 fair value Level 3 estimate was less than the Refining reporting unit’s carrying value by an amount that exceeded the existing goodwill balance of the reporting unit.  As a result, the Refining reporting unit recorded aunit’s goodwill impairment charge of $1,845 million and reduced its goodwill balancewas impaired to 0. As part of our impairment analysis, the fair value of all reporting units was reconciled to the company’s market capitalization.

See Note 7—Goodwill,Impairments, for additional information on the goodwill impairment.above impairments.


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Note 14—Pension and Postretirement Plans

The components of net periodic benefit cost for the three and six months ended June 30, 20202021 and 2019,2020, were as follows:
Millions of Dollars Millions of Dollars
Pension BenefitsOther Benefits Pension BenefitsOther Benefits
202020192020  2019   202120202021 2020 
U.S.Int’l.U.S.Int’l.U.S.Int’l.U.S.Int’l.
Components of Net Periodic Benefit CostComponents of Net Periodic Benefit CostComponents of Net Periodic Benefit Cost
Three Months Ended June 30Three Months Ended June 30Three Months Ended June 30
Service costService cost$34   31     Service cost$37 8 34 2 
Interest costInterest cost24   27     Interest cost20 4 24 1 
Expected return on plan assetsExpected return on plan assets(42) (12) (35) (12) —  —  Expected return on plan assets(41)(14)(42)(12)0 
Amortization of prior service credit—  —  —  —  —  (1) 
Recognized net actuarial loss15   13   —  —  
Recognized net actuarial loss (gain)Recognized net actuarial loss (gain)14 6 15 (1)
SettlementsSettlements39  —   —  —  —  Settlements29 0 39 0 
Net periodic benefit cost*Net periodic benefit cost*$70   38     Net periodic benefit cost*$59 4 70 2 
Six Months Ended June 30Six Months Ended June 30Six Months Ended June 30
Service costService cost$67  14  63  12    Service cost$74 17 67 14 3 
Interest costInterest cost49  11  54  13    Interest cost40 9 49 11 2 
Expected return on plan assetsExpected return on plan assets(83) (25) (71) (23) —  —  Expected return on plan assets(82)(29)(83)(25)0 
Amortization of prior service creditAmortization of prior service credit—  —  —  —  (1) (1) Amortization of prior service credit0 0 (1)(1)
Recognized net actuarial loss29   26   —  —  
Recognized net actuarial loss (gain)Recognized net actuarial loss (gain)29 12 29 (1)
SettlementsSettlements39  —   —  —  —  Settlements29 0 39 0 
Net periodic benefit cost*Net periodic benefit cost*$101   78     Net periodic benefit cost*$90 9 101 3 
* Included in the “Operating expenses” and “Selling, general and administrative expenses” line items on our consolidated statement of operations.* Included in the “Operating expenses” and “Selling, general and administrative expenses” line items on our consolidated statement of operations.* Included in the “Operating expenses” and “Selling, general and administrative expenses” line items on our consolidated statement of operations.


During the six months ended June 30, 2020,2021, we contributed $13$10 million to our U.S. pension and other postretirement benefit plans and $13 million to our international pension plans. We currently expect to make additional contributions of approximately $24$35 million to our U.S. pension and other postretirement benefit plans and $13$15 million to our international pension plans during the remainder of 2020.2021.

During the six months ended June 30, 2020, we estimated that2021, our lump-sum benefit payments will exceedexceeded the sum of service and interest costs for the plan year for our U.S. qualified and non-qualified pension plans. As a result, we recognized a portion of prior actuarial losses, or pension settlement expense, of $34$27 million related to our U.S. qualified pension plan and $5$2 million related to our U.S. non-qualified pension plan. In conjunction with the recognition of pension settlement expense, the plan assets and projected benefit obligation of our U.S. qualified pension plan were remeasured as of June 30, 2020.2021. At the remeasurement date, the net pension liability increaseddecreased by $300$210 million resulting in a corresponding increase to other comprehensive loss.income for the second quarter of 2021. The increasedecrease in the net pension liability was primarily due to a declinean increase in the discount rate used to value the projected benefit obligation from 3.3%2.5% to 2.7%2.9% and a decreasean increase in the fair value of plan assets during the six months endedfrom December 31, 2020, to June 30, 2020.2021.


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Note 15—Accumulated Other Comprehensive Loss

Changes in the balances of each component of accumulated other comprehensive loss were as follows:

Millions of Dollars Millions of Dollars
Defined Benefit PlansForeign Currency TranslationHedgingAccumulated Other Comprehensive Loss Defined Benefit PlansForeign Currency TranslationHedgingAccumulated Other Comprehensive Loss
December 31, 2020December 31, 2020$(809)25 (5)(789)
Other comprehensive income before reclassificationsOther comprehensive income before reclassifications181 4 1 186 
Amounts reclassified from accumulated other comprehensive lossAmounts reclassified from accumulated other comprehensive loss
Defined benefit plans*Defined benefit plans*
Amortization of net actuarial loss, prior service credit and settlementsAmortization of net actuarial loss, prior service credit and settlements53   53 
Foreign currency translationForeign currency translation 0  0 
HedgingHedging  1 1 
Net current period other comprehensive incomeNet current period other comprehensive income234 4 2 240 
June 30, 2021June 30, 2021$(575)29 (3)(549)
December 31, 2019December 31, 2019$(656) (131) (1) (788) December 31, 2019$(656)(131)(1)(788)
Other comprehensive loss before reclassificationsOther comprehensive loss before reclassifications(223) (195) (8) (426) Other comprehensive loss before reclassifications(223)(195)(8)(426)
Amounts reclassified from accumulated other comprehensive lossAmounts reclassified from accumulated other comprehensive lossAmounts reclassified from accumulated other comprehensive loss
Defined benefit plans*Defined benefit plans*Defined benefit plans*
Amortization of net actuarial loss, prior service credit and settlementsAmortization of net actuarial loss, prior service credit and settlements60  —  —  60  Amortization of net actuarial loss, prior service credit and settlements60 — — 60 
Foreign currency translationForeign currency translation—  —  —  —  Foreign currency translation— — 
HedgingHedging—  —    Hedging— — 
Net current period other comprehensive lossNet current period other comprehensive loss(163) (195) (7) (365) Net current period other comprehensive loss(163)(195)(7)(365)
OtherOther—   —   Other
June 30, 2020June 30, 2020$(819) (321) (8) (1,148) June 30, 2020$(819)(321)(8)(1,148)
December 31, 2018$(472) (228)  (692) 
Other comprehensive income (loss) before reclassifications (6) (7) (9) 
Amounts reclassified from accumulated other comprehensive loss
Defined benefit plans*
Amortization of net actuarial loss, prior service credit and settlements26  —  —  26  
Foreign currency translation—  —  —  —  
Hedging—  —  (3) (3) 
Net current period other comprehensive income (loss)30  (6) (10) 14  
Income taxes reclassified to retained earnings**(93)   (89) 
June 30, 2019$(535) (232) —  (767) 
* Included in the computation of net periodic benefit cost. See Note 14—Pension and Postretirement Plans, for additional information.* Included in the computation of net periodic benefit cost. See Note 14—Pension and Postretirement Plans, for additional information.* Included in the computation of net periodic benefit cost. See Note 14—Pension and Postretirement Plans, for additional information.
** As of January 1, 2019, stranded income taxes related to the enactment of the Tax Act in December 2017 were reclassified to retained earnings upon adoption of ASU No. 2018-02.

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Note 16—Related Party Transactions

Significant transactions with related parties were:

Millions of Dollars Millions of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
2020  2019  2020  2019   2021 2020 2021 2020 
Operating revenues and other income (a)Operating revenues and other income (a)$353  796  887  1,479  Operating revenues and other income (a)$959 353 1,729 887 
Purchases (b)Purchases (b)1,130  3,260  3,256  5,928  Purchases (b)3,452 1,130 5,809 3,256 
Operating expenses and selling, general and administrative expenses (c)Operating expenses and selling, general and administrative expenses (c)55   106  17  Operating expenses and selling, general and administrative expenses (c)67 55 135 106 

(a)We sold NGL, other petrochemical feedstocks and solvents to Chevron Phillips Chemical Company LLC (CPChem), NGL and certain feedstocks to DCP Midstream, gas oil and hydrogen feedstocks to Excel Paralubes (Excel), and refined petroleum products to several of our equity affiliates in the M&SMarketing and Specialties segment, including OnCue and 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 NGLsolvents from WRB and also acted as agent for WRB in distributing solvents.WRB. We also purchased natural gas and NGL from DCP Midstream and 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 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.


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Note 17—Segment Disclosures and Related Information

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, processing, and marketing services, mainly in the United States. The Midstream segment includes our master limited partnership (MLP), Phillips 66 Partners, as well as our 50% equity investment in DCP Midstream.

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, distillates and aviation fuels, at 13 refineries in the United States and Europe.

4)Marketing and Specialties—Purchases for resale and markets refined petroleum products, mainly in the United States and Europe. In addition, this segment includes the manufacturing and marketing of specialty products.

Corporate and Other includes general corporate overhead, interest expense, our investment in new technologies, and various other corporate activities. Corporate assets include all cash, cash equivalents and income tax-related assets.

Intersegment sales are at prices that we believe approximate market.

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Analysis of Results by Operating Segment

Millions of Dollars Millions of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
2020  2019  2020  2019   2021 2020 2021 2020 
Sales and Other Operating Revenues*
Sales and Other Operating Revenues*
Sales and Other Operating Revenues*
MidstreamMidstreamMidstream
Total salesTotal sales$1,100  1,709  2,638  3,606  Total sales$2,598 1,100 4,982 2,638 
Intersegment eliminationsIntersegment eliminations(382) (460) (877) (1,044) Intersegment eliminations(709)(382)(1,336)(877)
Total MidstreamTotal Midstream718  1,249  1,761  2,562  Total Midstream1,889 718 3,646 1,761 
ChemicalsChemicals    Chemicals1 2 
RefiningRefiningRefining
Total salesTotal sales7,352  20,387  21,133  37,248  Total sales18,680 7,352 33,733 21,133 
Intersegment eliminationsIntersegment eliminations(4,437) (12,788) (12,070) (22,556) Intersegment eliminations(11,517)(4,437)(19,973)(12,070)
Total RefiningTotal Refining2,915  7,599  9,063  14,692  Total Refining7,163 2,915 13,760 9,063 
Marketing and SpecialtiesMarketing and SpecialtiesMarketing and Specialties
Total salesTotal sales7,493  19,687  21,742  34,929  Total sales18,504 7,493 32,102 21,742 
Intersegment eliminationsIntersegment eliminations(220) (696) (790) (1,249) Intersegment eliminations(560)(220)(893)(790)
Total Marketing and SpecialtiesTotal Marketing and Specialties7,273  18,991  20,952  33,680  Total Marketing and Specialties17,944 7,273 31,209 20,952 
Corporate and OtherCorporate and Other  13  14  Corporate and Other5 12 13 
Consolidated sales and other operating revenuesConsolidated sales and other operating revenues$10,913  27,847  31,791  50,950  Consolidated sales and other operating revenues$27,002 10,913 48,629 31,791 
* See Note 2—Sales and Other Operating Revenues, for further details on our disaggregated sales and other operating revenues.* See Note 2—Sales and Other Operating Revenues, for further details on our disaggregated sales and other operating revenues.* See Note 2—Sales and Other Operating Revenues, for further details on our disaggregated sales and other operating revenues.
Income (Loss) Before Income TaxesIncome (Loss) Before Income TaxesIncome (Loss) Before Income Taxes
MidstreamMidstream$324  423  (378) 739  Midstream$312 324 388 (378)
ChemicalsChemicals42  275  211  502  Chemicals623 42 777 211 
RefiningRefining(878) 983  (3,139) 785  Refining(729)(878)(1,769)(3,139)
Marketing and SpecialtiesMarketing and Specialties286  353  799  558  Marketing and Specialties476 286 766 799 
Corporate and OtherCorporate and Other(219) (205) (416) (415) Corporate and Other(246)(219)(497)(416)
Consolidated income (loss) before income taxesConsolidated income (loss) before income taxes$(445) 1,829  (2,923) 2,169  Consolidated income (loss) before income taxes$436 (445)(335)(2,923)

 Millions of Dollars
 June 30
2020
December 31
2019
Total Assets
Midstream$15,447  15,716  
Chemicals6,148  6,249  
Refining21,981  25,150  
Marketing and Specialties7,246  8,659  
Corporate and Other3,696  2,946  
Consolidated total assets$54,518  58,720  

 Millions of Dollars
 June 30
2021
December 31
2020
Total Assets
Midstream$15,190 15,596 
Chemicals6,454 6,183 
Refining22,437 20,404 
Marketing and Specialties8,672 7,180 
Corporate and Other4,224 5,358 
Consolidated total assets$56,977 54,721 

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Note 18—Income Taxes

Historically, we have calculated the provision for income taxes during interim reporting periods by applying an estimate of the annual effective tax rate for the full year to income (loss) for the interim period. In the second quarter of 2020, we concluded that we could not calculate a reliable estimate of our annual effective tax rate due to the range of potential impacts the global COVID-19 pandemic may have on our business and results of operations. Accordingly, we computed the effective tax rate for the six-month period ending June 30, 2020, using actual results.

Our effective income tax rate for the three and six months ended June 30, 2020,2021, was 14% and 21%, respectively, compared with 85% and 15%, respectively, compared with 18% for the corresponding periods of 2019.2020. The increasedecrease in our effective tax rate for the three months ended June 30, 2020, is2021, was primarily attributable to thean adjustment required in the second quarter for the first-quarterof 2020 resultsrelated to reflect thea change in methodology discussed above.The decrease in our effective tax rateused to calculate the provision for the six months ended June 30, 2020, is primarily attributable to the impact of the nondeductible goodwill impairment, partially offset byincome taxes based on actual results and the ability provided under the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) to carry back a 2020 net operating loss to a year with a 35% income tax rate. Also contributing to the decrease were enacted income tax rate as well as foreign operationschanges and income attributable to noncontrolling interests.

interests, partially offset by state income taxes. The effective income tax rate for the three months ended June 30, 2020, varied from the U.S. federal statutory income tax rate of 21%, primarily attributable to the adjustment requiredincrease in the second quarter for the first-quarter 2020 results to reflect the change in methodology discussed above. Theour effective income tax rate for the six months ended June 30, 2020, varied from the U.S. federal statutory rate of 21%,2021, was primarily due to the impact of thea prior-year nondeductible goodwill impairment and enacted income tax rate changes, partially offset by the ability provided under the CARES Act to carry back a 2020 net operating loss to a year with a 35% income tax rate.rate, income attributable to noncontrolling interests and foreign operations.

The effective income tax rate for the three months ended June 30, 2021, varied from the U.S. federal statutory income tax rate of 21%, primarily due to income attributable to noncontrolling interests, foreign operations and enacted income tax rate changes.

We received a U.S. federal income tax refund of $1.1 billion in the second quarter of 2021. An income tax receivable of $557$657 million is included in the “Accounts and notes receivable” line item on our consolidated balance sheet as of June 30, 2020, which reflects our estimate of the tax benefit that we expect to realize within the next 12 months.
2021.






























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Note 19—Phillips 66 Partners LP

Phillips 66 Partners, headquartered in Houston, Texas, is a publicly traded MLP formed in 2013 to own, operate, develop and acquire primarily fee-based midstream assets. Phillips 66 Partners’ operations currently consist of crude oil, refined petroleum product and NGL transportation, fractionation, processing, terminaling, and storage assets.

We consolidate Phillips 66 Partners because we determined it is a VIE of which we are the primary beneficiary. As general partner of Phillips 66 Partners, we have the ability to control its financial interests, as well as the ability to direct the activities that most significantly impact its economic performance. As a result of this consolidation, the public common and perpetual convertible preferred unitholders’ ownership interests in Phillips 66 Partners are reflected as noncontrolling interests in our financial statements. In June 2021, Phillips 66 Partners repurchased 368,528 of its outstanding perpetual convertible preferred units for $24 million in cash. Upon the repurchase, these preferred units were canceled and are no longer outstanding. At June 30, 2020,2021, we owned 170 million Phillips 66 Partners common units, representing a 74% limited partner interest in Phillips 66 Partners, while the public owned a 26% limited partner interest and 13.813.5 million perpetual convertible preferred units.

The most significant assets of Phillips 66 Partners 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 Millions of Dollars
June 30
2020
December 31
2019
June 30
2021
December 31
2020
Cash and cash equivalents$ 286  
Equity investments*Equity investments*3,340  2,961  Equity investments*$2,962 3,244 
Net properties, plants and equipmentNet properties, plants and equipment3,500  3,349  Net properties, plants and equipment3,653 3,639 
Short-term debtShort-term debt265  25  Short-term debt465 465 
Long-term debtLong-term debt3,442  3,491  Long-term debt3,445 3,444 
* Included in the “Investments and long-term receivables” line item on the Phillips 66 consolidated balance sheet.* Included in the “Investments and long-term receivables” line item on the Phillips 66 consolidated balance sheet.* Included in the “Investments and long-term receivables” line item on the Phillips 66 consolidated balance sheet.


For the six months ended June 30, 2020, on a settlement-date basis, Phillips 66 Partners generated net proceeds
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Table of $2 million from common units issued under its continuous offering of common units, or at-the-market (ATM) programs, with 0 issuances in the second quarter of 2020. For the three and six months ended June 30, 2019, Phillips 66 Partners generated net proceeds of $10 million and $42 million, respectively, under its ATM programs.Contents

Gray Oak Pipeline, LLC was formed to develop and construct the Gray Oak Pipeline, which transports crude oil from the Permian and Eagle Ford to Texas Gulf Coast destinations that include Corpus Christi, Texas, and the Sweeny area, including the Phillips 66our Sweeny Refinery, as well as access to the Houston market.Refinery. Phillips 66 Partners has a consolidated holding company that owns 65% of Gray Oak Pipeline, LLC. In December 2018, a third party exercised its option to acquireacquired a 35% interest in the holding company. Because the holding company’s sole asset was its ownership interest in Gray Oak Pipeline, LLC, which was considered a financial asset, and because certain restrictions were placed on the third party’s ability to transfer or sell its interest in the holding company during the construction of the Gray Oak Pipeline, the legal sale of the 35% interest did not qualify as a sale under GAAP at that time. The Gray Oak Pipeline commenced full operations in the second quarter of 2020, and the restrictions placed on the co-venturer were lifted on June 30, 2020, resulting in the recognition of the sale under GAAP. Accordingly, at June 30, 2020, the co-venturer’s 35% interest in the holding company was recharacterized from a long-term obligation to a noncontrolling interest on our consolidated balance sheet. In addition,sheet, and the premium of $84 million previously paid by the co-venturer in 2019 was recharacterized from a long-term obligation to a gain in our consolidated statement of operations for the three and six months ended June 30, 2020.operations. For the six months ended June 30, 2020, the co-venturer contributed an aggregate of $61 million to the holding company to fund its portion of Gray Oak Pipeline, LLC’s cash calls. ExcludingPhillips 66 Partners’ effective ownership interest in Gray Oak Pipeline, LLC is 42.25% , after considering the co-venturer’s 35% interest in the consolidated holding company, Phillips 66 Partners has an effective ownership interest of 42.25% in Gray Oak Pipeline, LLC. company.

See Note 5—Investments, Loans and Long-Term Receivables, for further discussion regarding Phillips 66 Partners’ investmentinvestments in Gray Oak Pipeline, LLC, Dakota Access and ETCO, and Liberty.


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Note 20—Condensed Consolidating Financial Information

Phillips 66 has senior notes outstanding, the payment obligations of which are fully and unconditionally guaranteed by Phillips 66 Company, a 100 percent-owned subsidiary. The following condensed consolidating financial information presents the results of operations, financial position and cash flows for:

Phillips 66 and Phillips 66 Company (in each case, reflecting investments in subsidiaries utilizing the equity method of accounting).
All other nonguarantor subsidiaries.
The consolidating adjustments necessary to present Phillips 66’s results on a consolidated basis.

This condensed consolidating financial information should be read in conjunction with the accompanying consolidated financial statements and notes.
Millions of Dollars
Three Months Ended June 30, 2020
Statement of OperationsPhillips 66Phillips 66 CompanyAll Other SubsidiariesConsolidating AdjustmentsTotal Consolidated
Revenues and Other Income (Loss)
Sales and other operating revenues$—  8,236  2,677  —  10,913  
Equity in earnings (losses) of affiliates(86) 230  174  (161) 157  
Net gain on dispositions—  —  85  —  85  
Other income—  19   —  28  
Intercompany revenues 604  1,553  (2,158) —  
Total Revenues and Other Income (Loss)(85) 9,089  4,498  (2,319) 11,183  
Costs and Expenses
Purchased crude oil and products—  7,990  3,665  (2,047) 9,608  
Operating expenses—  810  248  (32) 1,026  
Selling, general and administrative expenses 319  92  (3) 409  
Depreciation and amortization—  235  108  —  343  
Taxes other than income taxes—  86  28  —  114  
Accretion on discounted liabilities—    —   
Interest and debt expense92  22  79  (76) 117  
Foreign currency transaction losses—  —   —   
Total Costs and Expenses93  9,466  4,227  (2,158) 11,628  
Income (loss) before income taxes(178) (377) 271  (161) (445) 
Income tax benefit(37) (291) (50) —  (378) 
Net Income (Loss)(141) (86) 321  (161) (67) 
Less: net income attributable to noncontrolling interests—  —  74  —  74  
Net Income (Loss) Attributable to Phillips 66$(141) (86) 247  (161) (141) 
Comprehensive Income (Loss)$(298) (243) 343  (26) (224) 
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Millions of Dollars
Three Months Ended June 30, 2019
Statement of OperationsPhillips 66Phillips 66 CompanyAll Other SubsidiariesConsolidating AdjustmentsTotal Consolidated
Revenues and Other Income
Sales and other operating revenues$—  21,698  6,149  —  27,847  
Equity in earnings of affiliates1,495  1,000  202  (2,049) 648  
Other income—  22   —  23  
Intercompany revenues—  722  4,095  (4,817) —  
Total Revenues and Other Income1,495  23,442  10,447  (6,866) 28,518  
Costs and Expenses
Purchased crude oil and products—  20,185  9,082  (4,713) 24,554  
Operating expenses—  917  271  (23) 1,165  
Selling, general and administrative expenses 319  91  (3) 408  
Depreciation and amortization—  229  105  —  334  
Impairments—    —   
Taxes other than income taxes—  70  27  —  97  
Accretion on discounted liabilities—    (1)  
Interest and debt expense89  37  66  (77) 115  
Foreign currency transaction losses—  —   —   
Total Costs and Expenses90  21,763  9,653  (4,817) 26,689  
Income before income taxes1,405  1,679  794  (2,049) 1,829  
Income tax expense (benefit)(19) 184  160  —  325  
Net Income1,424  1,495  634  (2,049) 1,504  
Less: net income attributable to noncontrolling interests—  —  80  —  80  
Net Income Attributable to Phillips 66$1,424  1,495  554  (2,049) 1,424  
Comprehensive Income$1,366  1,437  574  (1,931) 1,446  
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Millions of Dollars
Six Months Ended June 30, 2020
Statement of OperationsPhillips 66Phillips 66 CompanyAll Other SubsidiariesConsolidating AdjustmentsTotal Consolidated
Revenues and Other Income (Loss)
Sales and other operating revenues$—  23,746  8,045  —  31,791  
Equity in earnings (losses) of affiliates(2,506) (131) 413  2,746  522  
Net gain on dispositions—   85  —  86  
Other income—  17  11  —  28  
Intercompany revenues 1,534  3,971  (5,506) —  
Total Revenues and Other Income (Loss)(2,505) 25,167  12,525  (2,760) 32,427  
Costs and Expenses
Purchased crude oil and products—  22,976  10,354  (5,282) 28,048  
Operating expenses—  1,927  502  (62) 2,367  
Selling, general and administrative expenses 530  199  (5) 728  
Depreciation and amortization—  470  215  —  685  
Impairments—  1,805  1,201  —  3,006  
Taxes other than income taxes—  209  62  —  271  
Accretion on discounted liabilities—    —  11  
Interest and debt expense170  58  157  (157) 228  
Foreign currency transaction losses—  —   —   
Total Costs and Expenses174  27,984  12,698  (5,506) 35,350  
Loss before income taxes(2,679) (2,817) (173) 2,746  (2,923) 
Income tax benefit(42) (311) (76) —  (429) 
Net Loss(2,637) (2,506) (97) 2,746  (2,494) 
Less: net income attributable to noncontrolling interests—  —  143  —  143  
Net Loss Attributable to Phillips 66$(2,637) (2,506) (240) 2,746  (2,637) 
Comprehensive Loss$(3,002) (2,871) (284) 3,298  (2,859) 
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Millions of Dollars
Six Months Ended June 30, 2019
Statement of OperationsPhillips 66Phillips 66 CompanyAll Other SubsidiariesConsolidating AdjustmentsTotal Consolidated
Revenues and Other Income
Sales and other operating revenues$—  39,113  11,837  —  50,950  
Equity in earnings of affiliates1,776  1,431  367  (2,410) 1,164  
Net gain on dispositions—  —   —   
Other income—  42  19  —  61  
Intercompany revenues—  1,883  7,310  (9,193) —  
Total Revenues and Other Income1,776  42,469  19,534  (11,603) 52,176  
Costs and Expenses
Purchased crude oil and products—  37,265  17,336  (8,992) 45,609  
Operating expenses—  1,917  597  (42) 2,472  
Selling, general and administrative expenses 574  201  (5) 774  
Depreciation and amortization—  456  209  —  665  
Impairments—    —   
Taxes other than income taxes—  165  60  —  225  
Accretion on discounted liabilities—    —  11  
Interest and debt expense182  73  133  (154) 234  
Foreign currency transaction losses—  —  14  —  14  
Total Costs and Expenses186  40,460  18,554  (9,193) 50,007  
Income before income taxes1,590  2,009  980  (2,410) 2,169  
Income tax expense (benefit)(38) 233  200  —  395  
Net Income1,628  1,776  780  (2,410) 1,774  
Less: net income attributable to noncontrolling interests—  —  146  —  146  
Net Income Attributable to Phillips 66$1,628  1,776  634  (2,410) 1,628  
Comprehensive Income$1,642  1,790  785  (2,429) 1,788  
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Millions of Dollars
June 30, 2020
Balance SheetPhillips 66Phillips 66 CompanyAll Other SubsidiariesConsolidating AdjustmentsTotal Consolidated
Assets
Cash and cash equivalents$—  661  1,229  —  1,890  
Accounts and notes receivable—  3,661  3,154  (1,963) 4,852  
Inventories—  3,622  1,514  —  5,136  
Prepaid expenses and other current assets 377  243  —  621  
Total Current Assets 8,321  6,140  (1,963) 12,499  
Investments and long-term receivables31,289  24,786  10,747  (53,194) 13,628  
Net properties, plants and equipment—  13,725  10,557  —  24,282  
Goodwill—  1,047  378  —  1,425  
Intangibles—  740  134  —  874  
Other assets12  4,195  673  (3,070) 1,810  
Total Assets$31,302  52,814  28,629  (58,227) 54,518  
Liabilities and Equity
Accounts payable$—  4,796  2,535  (1,963) 5,368  
Short-term debt1,497  15  271  —  1,783  
Accrued income and other taxes—  439  607  —  1,046  
Employee benefit obligations—  354  41  —  395  
Other accruals76  1,292  417  (354) 1,431  
Total Current Liabilities1,573  6,896  3,871  (2,317) 10,023  
Long-term debt8,938  158  3,567  —  12,663  
Asset retirement obligations and accrued environmental costs—  450  175  —  625  
Deferred income taxes—  3,801  1,673  (3) 5,471  
Employee benefit obligations—  1,142  218  —  1,360  
Other liabilities and deferred credits46  10,806  5,714  (15,485) 1,081  
Total Liabilities10,557  23,253  15,218  (17,805) 31,223  
Common stock3,232  25,873  9,588  (35,461) 3,232  
Retained earnings18,661  4,836  1,700  (6,566) 18,631  
Accumulated other comprehensive loss(1,148) (1,148) (457) 1,605  (1,148) 
Noncontrolling interests—  —  2,580  —  2,580  
Total Liabilities and Equity$31,302  52,814  28,629  (58,227) 54,518  
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Millions of Dollars
December 31, 2019
Balance SheetPhillips 66Phillips 66 CompanyAll Other SubsidiariesConsolidating AdjustmentsTotal Consolidated
Assets
Cash and cash equivalents$—  136  1,478  —  1,614  
Accounts and notes receivable86  6,334  4,148  (2,058) 8,510  
Inventories—  2,594  1,182  —  3,776  
Prepaid expenses and other current assets 362  131  —  495  
Total Current Assets88  9,426  6,939  (2,058) 14,395  
Investments and long-term receivables33,082  25,039  10,989  (54,539) 14,571  
Net properties, plants and equipment—  13,676  10,110  —  23,786  
Goodwill—  2,853  417  —  3,270  
Intangibles—  732  137  —  869  
Other assets14  4,290  714  (3,189) 1,829  
Total Assets$33,184  56,016  29,306  (59,786) 58,720  
Liabilities and Equity
Accounts payable$—  7,024  3,609  (2,058) 8,575  
Short-term debt500  16  31  —  547  
Accrued income and other taxes—  386  593  —  979  
Employee benefit obligations—  648  62  —  710  
Other accruals65  850  249  (329) 835  
Total Current Liabilities565  8,924  4,544  (2,387) 11,646  
Long-term debt7,434  155  3,627  —  11,216  
Asset retirement obligations and accrued environmental costs—  460  178  —  638  
Deferred income taxes—  3,727  1,828  (2) 5,553  
Employee benefit obligations—  825  219  —  1,044  
Other liabilities and deferred credits245  8,975  5,465  (13,231) 1,454  
Total Liabilities8,244  23,066  15,861  (15,620) 31,551  
Common stock3,634  25,838  9,516  (35,354) 3,634  
Retained earnings22,094  7,900  1,940  (9,870) 22,064  
Accumulated other comprehensive loss(788) (788) (270) 1,058  (788) 
Noncontrolling interests—  —  2,259  —  2,259  
Total Liabilities and Equity$33,184  56,016  29,306  (59,786) 58,720  

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Millions of Dollars
Six Months Ended June 30, 2020
Statement of Cash FlowsPhillips 66Phillips 66 CompanyAll Other SubsidiariesConsolidating AdjustmentsTotal Consolidated
Cash Flows From Operating Activities
Net Cash Provided by (Used in) Operating Activities$517  (253) 1,273  (556) 981  
Cash Flows From Investing Activities
Capital expenditures and investments—  (554) (1,350) 42  (1,862) 
Return of investments in equity affiliates—  —  88  —  88  
Proceeds from asset dispositions—  —   —   
Intercompany lending activities(1,751) 2,123  (372) —  —  
Advances/loans—related parties—  (210) (21) —  (231) 
Collection of advances/loans—related parties—  20  24  —  44  
Other—  (32) (32) —  (64) 
Net Cash Provided by (Used in) Investing Activities(1,751) 1,347  (1,662) 42  (2,024) 
Cash Flows From Financing Activities
Issuance of debt3,015  —  215  —  3,230  
Repayment of debt(500) (13) (28) —  (541) 
Issuance of common stock —  —  —   
Repurchase of common stock(443) —  —  —  (443) 
Dividends paid on common stock(789) (556) —  556  (789) 
Distributions to noncontrolling interests—  —  (127) —  (127) 
Net proceeds from issuance of Phillips 66 Partners LP common units—  —   —   
Other(55) —  82  (42) (15) 
Net Cash Provided by (Used in) Financing Activities1,234  (569) 144  514  1,323  
Effect of Exchange Rate Changes on Cash and Cash Equivalents—  —  (4) —  (4) 
Net Change in Cash and Cash Equivalents—  525  (249) —  276  
Cash and cash equivalents at beginning of period—  136  1,478  —  1,614  
Cash and Cash Equivalents at End of Period$—  661  1,229  —  1,890  
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Millions of Dollars
Six Months Ended June 30, 2019
Statement of Cash FlowsPhillips 66Phillips 66 CompanyAll Other SubsidiariesConsolidating AdjustmentsTotal Consolidated
Cash Flows From Operating Activities
Net Cash Provided by (Used in) Operating Activities$(130) 621  1,079  (118) 1,452  
Cash Flows From Investing Activities
Capital expenditures and investments—  (485) (1,243) —  (1,728) 
Return of investments in equity affiliates—   34  —  35  
Proceeds from asset dispositions—  —  83  —  83  
Intercompany lending activities1,730  (1,385) (345) —  —  
Advances/loans—related parties—  —  (95) —  (95) 
Collection of advances/loans—related parties—  —  95  —  95  
Other—  (24) 48  —  24  
Net Cash Provided by (Used in) Investing Activities1,730  (1,893) (1,423) —  (1,586) 
Cash Flows From Financing Activities
Issuance of debt—  —  860  —  860  
Repayment of debt—  (9) (588) —  (597) 
Issuance of common stock —  —  —   
Repurchase of common stock(799) —  —  —  (799) 
Dividends paid on common stock(770) —  (118) 118  (770) 
Distributions to noncontrolling interests—  —  (117) —  (117) 
Net proceeds from issuance of Phillips 66 Partners LP common units—  —  42  —  42  
Other(40) —  341  —  301  
Net Cash Provided by (Used in) Financing Activities(1,600) (9) 420  118  (1,071) 
Effect of Exchange Rate Changes on Cash and Cash Equivalents—  —   —   
Net Change in Cash and Cash Equivalents—  (1,281) 81  —  (1,200) 
Cash and cash equivalents at beginning of period—  1,648  1,371  —  3,019  
Cash and Cash Equivalents at End of Period$—  367  1,452  —  1,819  
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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” and similar expressions often identify forward-looking statements, but the absence of these words does not mean a statement is not forward-looking. The company does not undertake to update, revise or correct any of the forward-looking information unless required to do so under the federal securities laws. 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 terms “earnings” andor “loss” as used in Management’s Discussion and Analysis refer to net income (loss) 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 an energy manufacturing and logistics company with midstream, chemicals, refining, and marketing and specialties businesses. At June 30, 2020,2021, we had total assets of $54.5$57 billion. Our common stock trades on the New York Stock Exchange under the symbol PSX.

Executive Overview
The outbreak of Coronavirus Disease 2019 (COVID-19) and its development into a(COVID-19) pandemic continues to result in significantdisrupt economic disruptionactivities globally. Actions taken by governments to prevent the spread of the disease included travel and business restrictions, which resulted in substantial decreases in theReduced demand for many refined petroleum products particularly gasolineresulted in low refining margins and jet fuel. The lackdecreased volumes through refineries and logistics infrastructure in 2020. Since the beginning of 2021, demand for refined petroleum products has resulted in low crude oil pricesstarted to recover following the administration of COVID-19 vaccines and the easing of pandemic restrictions. Consequently, refining margins. Accordingly, crude oil producersmargins have shut in high cost production, and refiners have reduced crude oil processing rates.

improved, as has volume throughput. However, refining profitability remains challenged. The depth and duration of the economic consequences of the COVID-19 pandemic are currently unknown. The near-term outlook for petroleum product demand remains highlyremain uncertain prices remain volatile, and margins and volumes remain challenged. The adverse effects on our company have significantly impacted our second-quarter earnings and maywe continue to be significantmonitor our asset and investment portfolio. The consequences of the sustained disruption of economic activities by the pandemic may include additional asset impairments and portfolio rationalization in the near term.

During the first six months of 2020, we took the following significant steps to enhance our liquidity:

Secured a $2 billion, 364-day term loan facility, under which we have drawn $1 billion to date.
Issued $2 billion of senior unsecured notes in three tranches of three-, five-, and ten-year maturities.
Temporarily suspended our share repurchase programs.
Reduced our consolidated capital spending plans in 2020 by $700 million.
Executed a plan to reduce operating and administrative costs by $500 million in 2020.future.

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In the second quarter of 2020,2021, we reported a lossearnings of $141$296 million and generated cash from operating activities of $764 million and received approximately $2.0$1.7 billion, in net proceeds from two public offeringsincluding a U.S. federal income tax refund of senior unsecured notes.$1.1 billion. We used available cash to fundfor capital expenditures and investments of $939$380 million, repay $525dividend payments on our common stock of $394 million, and an additional member loan to an equity affiliate of maturing debt, and pay dividends of $393$90 million. We ended the second quarter of 20202021 with $1.9$2.2 billion of cash and cash equivalents and approximately $6.5$5.7 billion of total committed capacity available under our revolving credit facilities and new term loan facility.facilities.



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Business Environment
The Midstream segment includes our Transportation and Natural Gas Liquids (NGL)NGL businesses. Our Transportation business contains fee-based operations that are not directly exposed to commodity price risk. Our NGL business resultscontains both fee-based operations and operations that are primarily drivendirectly impacted by fractionation and terminaling margins, throughput volumes, and impacts from NGL prices. The Midstream segment also includes our 50% equity investment in DCP Midstream, LLC (DCP Midstream). Compared withDuring the second quarter of 2019,2021, NGL prices decreased inincreased significantly, compared with the second quarter of 2020, due to strong demand as economic activities gradually recovered following the negative economic impacts caused byadministration of COVID-19 vaccines and the COVID-19 pandemic.easing of pandemic restrictions.

The 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. During the second quarter of 2020,2021, the benchmark high-density polyethylene chain margin decreased,increased significantly, compared with the second quarter of 2019,2020. This significant increase was due to continued strong demand and tight supplies driven by the economicoperational impacts caused by the winter storms that occurred in the Central and Gulf Coast regions in the first quarter of the COVID-19 pandemic and recent capacity additions.2021.

Our Refining segment results are driven by several factors, including refining margins, refinery throughput, feedstock costs, product yields, turnaround activity, and other operating costs. The price of U.S. benchmark crude oil, West Texas Intermediate (WTI) at Cushing, Oklahoma, decreasedincreased to an average of $27.80$66.09 per barrel during the second quarter of 2020,2021, compared with an average of $59.80$27.80 per barrel in the second quarter of 2019, driven by a significant decline in global demand for refined petroleum products in the second quarter of 2020, as a result of the negative global economic impacts of the COVID-19 pandemic.2020. Market crack spreads are used as indicators of refining margins and measure the difference between market prices for refined petroleum products and crude oil. During the second quarter of 2020, the2021, worldwide market crack spreads were significantly lower compared withhigher than the second quarter of 2019,2020. The increases in crude oil prices and market crack spreads were mainly driven by a sharp declinesignificant increase in demand for refined petroleum products, resulting fromas economic activities gradually recovered following the significant global economic disruption caused byadministration of COVID-19 vaccines and the COVID-19 pandemic.easing of pandemic restrictions, as well as a tightening supply. In addition, in the second quarter of 2021, renewable identification number (RIN) costs increased significantly, compared with the corresponding period of 2020.

Results for our Marketing and Specialties (M&S) segment depend largely on marketing fuel and lubricant margins, and sales volumes of our refined petroleum and other specialty products. While M&S margins are primarily driven by market factors, largely determined by the relationship between supply and demand, marketing fuel margins, in particular, are influenced by the trend in spot prices for refined petroleum products. Generally speaking, a downward trend of spot prices has a favorable impact on marketing fuel margins, while an upward trend of spot prices has an unfavorable impact on marketing fuel margins. The significant global disruption caused by the COVID-19 also negatively impactedpandemic resulted in reduced demand for our refined petroleum and specialty products since March 2020. Following the administration of COVID-19 vaccines in 2021 and the second quartereasing of 2020pandemic restrictions, the global economy has begun to recover, and demand for refined petroleum and specialty products has significantly improved, compared with the second quarter of 2019.2020.
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RESULTS OF OPERATIONS

Unless otherwise indicated, discussion of results for the three and six months ended June 30, 2020,2021, is based on a comparison with the corresponding periods of 2019.2020.


Consolidated Results

A summary of income (loss) before income taxes by business segment with a reconciliation to net income (loss) attributable to Phillips 66 follows:

Millions of Dollars Millions of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
2020  2019  2020  2019   2021 2020 2021 2020 
MidstreamMidstream$324  423  (378) 739  Midstream$312 324 388 (378)
ChemicalsChemicals42  275  211  502  Chemicals623 42 777 211 
RefiningRefining(878) 983  (3,139) 785  Refining(729)(878)(1,769)(3,139)
Marketing and SpecialtiesMarketing and Specialties286  353  799  558  Marketing and Specialties476 286 766 799 
Corporate and OtherCorporate and Other(219) (205) (416) (415) Corporate and Other(246)(219)(497)(416)
Income (loss) before income taxesIncome (loss) before income taxes(445) 1,829  (2,923) 2,169  Income (loss) before income taxes436 (445)(335)(2,923)
Income tax expense (benefit)Income tax expense (benefit)(378) 325  (429) 395  Income tax expense (benefit)62 (378)(70)(429)
Net income (loss)Net income (loss)(67) 1,504  (2,494) 1,774  Net income (loss)374 (67)(265)(2,494)
Less: net income attributable to noncontrolling interestsLess: net income attributable to noncontrolling interests74  80  143  146  Less: net income attributable to noncontrolling interests78 74 93 143 
Net income (loss) attributable to Phillips 66Net income (loss) attributable to Phillips 66$(141) 1,424  (2,637) 1,628  Net income (loss) attributable to Phillips 66$296 (141)(358)(2,637)


Our earnings decreased $1,565net income attributable to Phillips 66 in the second quarter of 2021 was $296 million, compared with a net loss attributable to Phillips 66 of $141 million in the second quarter of 2020, mainly reflecting:

Lower realized refining margins and decreased refinery production.
Lower2020. The improvement reflects increased equity in earnings offrom affiliates in our Chemicals Refining and Midstream segments.

M&S segments, improved realized marketing fuel margins and sales volumes and higher realized refining margins. These decreasesincreases were partially offset by:

Anby an increase in income tax benefit recognized in the current quarter, compared with income tax expense recognized in the second quarter of 2019.taxes.

Our earnings decreased $4,265net loss attributable to Phillips 66 for the six months ended June 30, 2021, was $358 million, compared with $2,637 million for the six months ended June 30, 2020. The lower net loss attributable to Phillips 66 reflects a before-tax impairment of $198 million in the six-month periodfirst quarter of 2020, mainly reflecting:

A $1,8452021, compared with before-tax impairments of $3,006 million in the first quarter of 2020. Excluding these impairments, after-tax results for the six months ended June 30, 2021, decreased primarily due to a higher before-tax goodwill impairment inloss from our Refining segment.
A $1,161 million before-tax impairment of our investment in DCP Midstream.
Lower realized refining marginssegment and decreased refinery production.
Lower equity in earnings of affiliates in our Refining and Chemicals segments.

These decreases were partially offset by:

Ana lower income tax benefit, recognized in the current six-month period, compared with income tax expense recognized in the six-month period of 2019.partially offset by higher equity earnings from our Chemicals segment.

See the “Segment Results” section for additional information on our segment results.performance and Note 18—Income Taxes, in the Notes to Consolidated Financial Statements, for additional information on income taxes.

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Statement of Operations Analysis

Sales and other operating revenues for the second quarter and six-month period of 2020 decreased 61%2021 increased 147% and 38%53%, respectively, and purchased crude oil and products decreasedincreased 162% and 61% and 39%, respectively. These decreasesincreases were mainly due to lowerhigher prices for refined petroleum products, crude oil and NGL, as well as lowerincreased volumes.

Equity in earnings of affiliates decreased 76%increased $673 million and 55%$593 million in the second quarter and six-month period of 2020,2021, respectively. The decreaseincrease in both periods was primarily due to lower realized refining margins and decreased refinery production at WRB Refining LP (WRB) and lowerhigher equity earnings from CPChem. See Chemicals segment analysis in the “Segment Results” section for additional information on CPChem. The second-quarter decrease was also driven by lower equity earnings from certain of our Midstream joint ventures due to lower volumes.

Net gain on dispositions increased $85 milliondecreased 98% in both the second quarter and six-month period of 2020. The increase in both periods was mainly2021, primarily due to a before-tax gain of $84 million recognized in the second quarter of 2020 associated with a co-venturer’s prior-year acquisition of a 35%an ownership interest in the consolidated holding company that owns an interest in Gray Oak Pipeline, LLC. See Note 19—Phillips 66 Partners LP, in the Notes to Consolidated Financial Statements, for additional information.

Other incomeOperating expenses increased 15% and 8% in the second quarter and six-month period of 2021, respectively. The increase in the second quarter of 2021 was mainly due to higher refinery turnaround and maintenance expenses and increased utility costs. The increase in the six-month period of 2021 was primarily attributable to higher utility, maintenance and repair costs driven by the winter storms that occurred in the Central and Gulf Coast regions in February 2021.

Selling, general and administrative expenses increased 16% in the six-month period of 2021, primarily due to increased employee-related expenses and higher selling expenses due to rising refined petroleum product prices and demand, as well as a benefit received from a legal settlement in the first quarter of 2020.

Impairments decreased $33$2,808 million in the six-month period of 2020. The decrease2021. During the first quarter of 2021, a before-tax impairment of $198 million was primarily driven by a decreaserelated to Phillips 66 Partners LP’s investment in the fair value of deferred compensation investments inLiberty Pipeline project. In the first six monthsquarter of 2020, compared with an increasebefore-tax impairments of $3,006 million were recorded for our investment in the fair value of deferred compensation investmentsDCP Midstream and goodwill in the first six months of 2019, as well as a decrease in interest income due to lower interest rates in the first six months of 2020. our Refining segment. See Note 7—Impairments, and Note 13—Fair Value Measurements, in the Notes to Consolidated Financial Statements, for additional information on the fair value of the deferred compensation investments.

Operating expenses for the second quarter of 2020 decreased 12%, primarily due to lower refinery maintenance activities and decreased utility costs.

Impairments were $3,006 million for the six-month period of 2020, consisting of an impairment of $1,161 million associated with our investment in DCP Midstream, and a $1,845 million goodwill impairment in our Refining segment. See Note 5—Investments, Loans and Long-Term Receivables and Note 7—Goodwill, in the Notes to Consolidated Financial Statements, for additional information associated withregarding these impairments.

Interest and debt expense increased 22% and 27% in the second quarter and six-month period of 2021, respectively. The increase in both periods was primarily driven by lower capitalized interest due to the completion of capital projects and the placement of assets into service, as well as higher average debt principal balances.

We hadincome tax expense of $62 million and an income tax benefit of $70 million in the second quarter and six-month period of 2021, respectively, compared with an income tax benefit of $378 million and $429 million in the corresponding periods of 2020, respectively, reflecting before-tax income in the second quarter of 2021, and before-tax losses in the second quarter and six-month period of 2020 respectively, compared with income tax expenseand the six-month period of $325 million and $395 million, respectively, in the corresponding periods of 2019.2021. See Note 18—Income Taxes, in the Notes to Consolidated Financial Statements, for information regarding our effective income tax rates.

Net income attributable to noncontrolling interests decreased 35% in the six-month period of 2021, primarily due to lower net income from Phillips 66 Partners LP (Phillips 66 Partners) resulting from the before-tax impairment of $198 million associated with its investment in the Liberty Pipeline project described above.

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Segment Results

Midstream

Three Months Ended
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
2020  2019  2020  2019   2021 2020 2021 2020 
Millions of DollarsMillions of Dollars
Income (Loss) Before Income TaxesIncome (Loss) Before Income TaxesIncome (Loss) Before Income Taxes
TransportationTransportation$214  245  414  448  Transportation$224 214 231 414 
NGL and OtherNGL and Other78  143  257  233  NGL and Other79 78 114 257 
DCP MidstreamDCP Midstream32  35  (1,049) 58  DCP Midstream9 32 43 (1,049)
Total MidstreamTotal Midstream$324  423  (378) 739  Total Midstream$312 324 388 (378)

Thousands of Barrels Daily Thousands of Barrels Daily
Transportation VolumesTransportation VolumesTransportation Volumes
Pipelines*Pipelines*2,840  3,417  3,009  3,297  Pipelines*3,424 2,840 3,114 3,009 
TerminalsTerminals2,883  3,261  3,016  3,163  Terminals2,786 2,883 2,731 3,016 
Operating StatisticsOperating StatisticsOperating Statistics
NGL fractionated**NGL fractionated**170  232  184  233  NGL fractionated**401 170 382 184 
NGL production***NGL production***374  423  385  425  NGL production***406 374 381 385 
* Pipelines represent the sum of volumes transported through each separately tariffed consolidated pipeline segment.
** Excludes DCP Midstream.
*** Includes 100% of DCP Midstream’s volumes.

Dollars Per GallonDollars Per Gallon
Weighted-Average NGL Price*Weighted-Average NGL Price*Weighted-Average NGL Price*
DCP MidstreamDCP Midstream$0.32  0.51  0.36  0.56  DCP Midstream$0.71 0.32 0.70 0.36 
* Based on index prices from the Mont Belvieu market hub, which are weighted by NGL component mix.* Based on index prices from the Mont Belvieu market hub, which are weighted by NGL component mix.* Based on index prices from the Mont Belvieu market hub, which are weighted by NGL component mix.


The Midstream segment provides crude oil and refined petroleum product transportation, terminaling and processing services, as well as natural gas and NGL transportation, storage, fractionation, processing and marketing services, mainly in the United States. This segment includes our master limited partnership (MLP), Phillips 66 Partners, LP (Phillips 66 Partners), as well as our 50% equity investment in DCP Midstream, which includes the operations of DCP Midstream, LP (DCP Partners), its MLP.

TheResults from our Midstream segment had before-tax income of $324 million and a before-tax loss of $378decreased $12 million in the second quarter of 2021 and increased $766 million in the six-month period of 2020, respectively, compared with before-tax income of $423 million and $7392021.

Results from our Transportation business increased $10 million in the corresponding periodssecond quarter of 2019, respectively.2021, and decreased $183 million in the six-month period of 2021. The decreaseincrease in the second quarter of 2021 was mainly driven by higher pipeline volumes resulting from improved refinery utilization rates and increased earnings from equity affiliates. These increases were partially offset by a before-tax incomegain of $84 million recognized in the second quarter of 2020 was primarily due to decreased results in our Transportation and NGL and Other businesses. The decreased results in the six-month period of 2020 were primarily driven by a $1,161 million before-tax impairment of our equity investment in DCP Midstream, slightly offset by improved results from our NGL and Other business.

Before-tax income from our Transportation business decreased $31 million in the second quarter of 2020 and $34 million in the six-month period of 2020. The decrease in both periods was primarily attributable to lower pipeline and terminal volumes driven by decreased refinery utilization, lower equity earnings from joint ventures, and higher operating costs. These decreases were partially offset by a gain of $84 million associated with a co-venturer’s prior-year acquisition of a 35%an ownership interest in the consolidated holding company that owns an interest in Gray Oak Pipeline, LLC. See Note 19—Phillips 66 Partners LP, in the Notes to Consolidated Financial Statements, for additional information. The decrease in the second quartersix-month period of 20202021 was also driven by unfavorable impactsprimarily attributable to a before-tax impairment of pipeline loss allowances due$198 million associated with Phillips 66 Partners’ decision to lower commodity prices.exit the Liberty Pipeline project.


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Before-tax incomeResults from our NGL and Other business decreased $65increased $1 million in the second quarter of 20202021, and increased $24decreased $143 million in the six-month period of 2020.2021. The decrease in the six-month period of 2021 was primarily due to higher operating expenses driven by the winter storms that occurred in the Gulf Coast region in February 2021, lower results from trading activities, reduced cargo margins at the Sweeny Hub, and decreased equity earnings. These decreases were partially offset by increased fractionation volumes from the startup of Fracs 2 and 3 at the Sweeny Hub in late 2020, leading to higher exported cargos.

Results from our investment in DCP Midstream decreased $23 million in the second quarter of 2021, and increased $1,092 million in the six-month period of 2021. The decrease in the second quarter of 20202021 was primarily due to unfavorable impacts associated with NGL inventory storagefrom DCP Midstream’s commodity price risk management as well as lower margins and volumes at the Sweeny Hub, partially offset by the startup of a new isomerization unit at our Lake Charles Refinery in the second half of 2019.activities. The increase in the six-month period of 2020 was mainly due to the startup of a new isomerization unit at our Lake Charles Refinery in the second half of 2019 and favorable inventory impacts, partially offset by implementation costs for additional fractionation capacity at the Sweeny Hub.

The before-tax income (loss) from our investment in DCP Midstream decreased $3 million in the second quarter of 2020 and $1,107 million in the six-month period of 2020. The decrease in the six-month period2021 was primarily due to a $1,161 million before-tax impairment of our equity investment in DCP Midstream as described below. Excluding the impairment, equity earnings from DCP Midstream increased $54 million in the six-month period ended June 30, 2020, mainly driven by the recognition of a benefit to equity earnings related to the amortization of the basis difference as described below, and lower operating costs.

The fair value of our investment in DCP Midstream depends on the market value of DCP Partners common units. The market value of DCP Partners common units declined by approximately 85%recorded in the first quarter of 2020.  As a result, at March 31, 2020, the fair value of our investment in DCP Midstream was significantly lower than its book value. We concluded the difference between its fair value

See Note 7—Impairments, and book value was not temporary primarily due to its magnitude. Accordingly, we recorded a $1,161 million before-tax impairment of our investment in the first quarter of 2020. This charge is included in the “Impairments” line item on our consolidated statement of operations for the six months ended June 30, 2020. The impairment increased the basis difference for our investment in DCP Midstream to $1.8 billion at March 31, 2020, which indicated the carrying value of our investment was lower than our share of DCP Midstream’s recorded net assets at March 31, 2020. The basis difference is being amortized and recognized as a benefit to equity earnings over a period of 22 years, which was the estimated remaining useful life of DCP Midstream’s properties, plants and equipment (PP&E) at March 31, 2020. Equity earnings for the three and six months ended June 30, 2020, were increased by approximately $20 million and $30 million, respectively, due to the amortization of the basis difference. See Note 13—Fair Value Measurements, in the Notes to Consolidated Financial Statements, for additional information onregarding impairments related to the techniques used to determine the fair value ofLiberty Pipeline project and our investment in DCP Midstream.

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
June 30
Six Months Ended
June 30
 2020  2019  2020  2019  
Millions of Dollars
Income Before Income Taxes$42  275  211  502  
 Three Months Ended
June 30
Six Months Ended
June 30
 2021 2020 2021 2020 
Millions of Dollars
Income Before Income Taxes$623 42 777 211 
 
Millions of Pounds Millions of Pounds
CPChem Externally Marketed Sales Volumes*CPChem Externally Marketed Sales Volumes*CPChem Externally Marketed Sales Volumes*
Olefins and PolyolefinsOlefins and Polyolefins4,890  4,592  9,490  9,284  Olefins and Polyolefins4,778 5,378 9,348 10,491 
Specialties, Aromatics and StyrenicsSpecialties, Aromatics and Styrenics1,014  969  2,202  2,038  Specialties, Aromatics and Styrenics1,234 1,014 2,215 2,202 
5,904  5,561  11,692  11,322  6,012 6,392 11,563 12,693 
* Represents 100% of CPChem’s outside sales of produced petrochemical products, as well as commission sales from equity affiliates.* Represents 100% of CPChem’s outside sales of produced petrochemical products, as well as commission sales from equity affiliates.* 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)103 %95  100  97  
Olefins and Polyolefins Capacity Utilization (percent)102 %103 88 100 


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. We structure our reporting of CPChem’s operations around two primary business lines: Olefins and Polyolefins (O&P) and Specialties, and Aromatics and Styrenics (SA&S).

Before-tax incomeResults from the Chemicals segment decreased $233increased $581 million in the second quarter of 2020 and $291$566 million in the six-month period of 2020. The decrease in the second quarter and six-month period of 20202021, respectively. The increase in both periods was mainlyprimarily driven by lowerhigher margins from CPChem’s portfolio of consolidatedreflecting strong demand, and joint venture assets, partially offset by higher sales volumes and lower utility costs. In addition, duringtight supplies following the first six months of 2020, CPChem recorded lower-of-cost-or-market write-downs of inventories valued on the last-in, first-out (LIFO) basis and an asset write-off by an international joint venture. Our portion of the inventory write-downs and asset write-off reduced our equity earnings from CPChemwinter storms that occurred in the second quarterCentral and six-month period of 2020 by $47 million and $71 million, respectively.Gulf Coast regions in February 2021.

See the “Executive Overview and Business Environment” section for information on market factors impacting this quarter’s results.
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Refining
Three Months Ended
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
2020  2019  2020  2019   2021 2020 2021 2020 
Millions of DollarsMillions of Dollars
Income (Loss) Before Income Taxes
Loss Before Income TaxesLoss Before Income Taxes
Atlantic Basin/EuropeAtlantic Basin/Europe$(227) 258  (864) 251  Atlantic Basin/Europe$(110)(227)(263)(864)
Gulf CoastGulf Coast(365) 222  (1,208) 104  Gulf Coast(264)(365)(517)(1,208)
Central CorridorCentral Corridor(104) 520  (331) 597  Central Corridor(82)(104)(330)(331)
West CoastWest Coast(182) (17) (736) (167) West Coast(273)(182)(659)(736)
WorldwideWorldwide$(878) 983  (3,139) 785  Worldwide$(729)(878)(1,769)(3,139)

Dollars Per BarrelDollars Per Barrel
Income (Loss) Before Income Taxes
Loss Before Income TaxesLoss Before Income Taxes
Atlantic Basin/EuropeAtlantic Basin/Europe$(5.80) 5.04  (10.74) 2.70  Atlantic Basin/Europe$(2.20)(5.80)(2.83)(10.74)
Gulf CoastGulf Coast(5.98) 2.88  (9.66) 0.73  Gulf Coast(3.81)(5.98)(4.17)(9.66)
Central CorridorCentral Corridor(5.01) 19.81  (7.50) 11.91  Central Corridor(3.49)(5.01)(7.64)(7.50)
West CoastWest Coast(7.07) (0.52) (13.73) (2.63) West Coast(9.70)(7.07)(12.19)(13.73)
WorldwideWorldwide(5.99) 5.25  (10.35) 2.25  Worldwide(4.26)(5.99)(5.63)(10.35)
Realized Refining Margins*Realized Refining Margins*Realized Refining Margins*
Atlantic Basin/EuropeAtlantic Basin/Europe$1.53  10.85  1.97  9.47  Atlantic Basin/Europe$4.63 1.53 4.73 1.97 
Gulf CoastGulf Coast0.36  8.20  3.64  6.93  Gulf Coast2.10 0.36 2.67 3.64 
Central CorridorCentral Corridor5.78  17.84  10.03  14.33  Central Corridor6.40 5.78 6.21 10.03 
West CoastWest Coast5.05  9.94  4.92  8.16  West Coast3.37 5.05 3.35 4.92 
WorldwideWorldwide2.60  11.37  4.96  9.46  Worldwide3.92 2.60 4.12 4.96 
* 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.
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Thousands of Barrels DailyThousands of Barrels Daily
Three Months Ended
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
Operating StatisticsOperating Statistics2020  2019  2020  2019  Operating Statistics20212020 2021 2020 
Refining operations*Refining operations*Refining operations*
Atlantic Basin/EuropeAtlantic Basin/EuropeAtlantic Basin/Europe
Crude oil capacityCrude oil capacity537  537  537  537  Crude oil capacity537 537 537 537 
Crude oil processedCrude oil processed402  519  420  473  Crude oil processed513 402 476 420 
Capacity utilization (percent)Capacity utilization (percent)75 %97  78  88  Capacity utilization (percent)96 %75 89 78 
Refinery productionRefinery production433  570  445  519  Refinery production552 433 517 445 
Gulf CoastGulf CoastGulf Coast
Crude oil capacityCrude oil capacity769  764  769  764  Crude oil capacity784 769 784 769 
Crude oil processedCrude oil processed609  757  627  706  Crude oil processed687 609 620 627 
Capacity utilization (percent)Capacity utilization (percent)79 %99  81  92  Capacity utilization (percent)88 %79 79 81 
Refinery productionRefinery production675  850  689  787  Refinery production763 675 683 689 
Central CorridorCentral CorridorCentral Corridor
Crude oil capacityCrude oil capacity530  515  530  515  Crude oil capacity531 530 531 530 
Crude oil processedCrude oil processed386  521  428  483  Crude oil processed462 386 423 428 
Capacity utilization (percent)Capacity utilization (percent)73 %101  81  94  Capacity utilization (percent)87 %73 80 81 
Refinery productionRefinery production396  541  442  504  Refinery production475 396 436 442 
West CoastWest CoastWest Coast
Crude oil capacityCrude oil capacity364  364  364  364  Crude oil capacity364 364 364 364 
Crude oil processedCrude oil processed263  317  271  312  Crude oil processed286 263 278 271 
Capacity utilization (percent)Capacity utilization (percent)72 %87  75  86  Capacity utilization (percent)79 %72 76 75 
Refinery productionRefinery production280  357  293  349  Refinery production307 280 298 293 
WorldwideWorldwideWorldwide
Crude oil capacityCrude oil capacity2,200  2,180  2,200  2,180  Crude oil capacity2,216 2,200 2,216 2,200 
Crude oil processedCrude oil processed1,660  2,114  1,746  1,974  Crude oil processed1,948 1,660 1,797 1,746 
Capacity utilization (percent)Capacity utilization (percent)75 %97  79  91  Capacity utilization (percent)88 %75 81 79 
Refinery productionRefinery production1,784  2,318  1,869  2,159  Refinery production2,097 1,784 1,934 1,869 
* Includes our share of equity affiliates.* Includes our share of equity affiliates.* Includes our share of equity affiliates.



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The Refining segment refines crude oil and other feedstocks into petroleum products, such as gasoline, distillates and aviation fuels, at 13 refineries in the United States and Europe.

The before-tax income (loss)Results from our Refining segment decreased $1,861improved by $149 million and $1,370 million, respectively, in the second quarter and six-month period of 2021. The improved results in the second quarter of 20202021 were primarily attributable to increased realized refining margins and $3,924higher refinery production driven by improved market demand, partially offset by higher refinery turnaround and other operating expenses. The improved results in the six-month period reflect a $1,845 million before-tax goodwill impairment recorded in the first quarter of 2020. Excluding this impairment, results decreased in the six-month period of 2020. The decreased results in both periods were primarily2021, mainly due to significantly lower realized refining margins, and higher utility costs primarily driven by the winter storms that occurred in the Central and Gulf Coast regions in February 2021. Realized refining margins were lower in the six-month period, as the benefit of improved market crack spreads was more than offset by higher RIN costs, lower clean product differentials and decreased refinery production across all regions. A sharp declinesecondary product margins.

Our worldwide refining crude oil capacity utilization rate was 88% and 81% in the second quarter and six-month period of 2021, respectively, compared with 75% and 79% in the second quarter and six-month period of 2020, respectively. The increase in both periods was primarily driven by improved market demand for refined petroleum products resulting from global economic disruption caused byfollowing the administration of COVID-19 vaccines and the easing of pandemic led to lower market crack spreads and reduced refinery production inrestrictions since the current periods. In addition, the decreased results in the six-month period included a goodwill impairmentbeginning of $1,845 million recognized in the first quarter of 2020.
2021
.

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Our stock price declined significantly in the first quarter of 2020 due to the volatility in global commodity and equity markets related to the COVID-19 pandemic and other factors.  We assessed our goodwill for impairment due to the decline in our market capitalization and concluded that the carrying value of our Refining reporting unit at March 31, 2020, was greater than its fair value by an amount in excess of its goodwill balance. Accordingly, we recorded a goodwill impairment charge of $1,845 million in our Refining segment during the first quarter of 2020. This charge is included in the “Impairments” line item on our consolidated statement of operations for the six months ended June 30, 2020. See Note 13—Fair Value Measurements for additional information on the techniques used to determine the fair value of our Refining reporting unit.

See the “Executive Overview and Business Environment” section for information on market factors impacting this quarter’s results.

Our worldwide refining crude oil capacity utilization rate was 75% and 79% in the second quarter and six-month period of 2020, respectively, compared with 97% and 91% in the second quarter and six-month period of 2019, respectively. These decreases were primarily due to reduced refining runs in the first half of 2020 driven by lower demand for refined petroleum products.








































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Marketing and Specialties

Three Months Ended
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
2020  2019  2020  2019  2021 2020 2021 2020 
Millions of DollarsMillions of Dollars
Income Before Income TaxesIncome Before Income TaxesIncome Before Income Taxes
Marketing and OtherMarketing and Other$255  294  726  432  Marketing and Other$389 255 600 726 
SpecialtiesSpecialties31  59  73  126  Specialties87 31 166 73 
Total Marketing and SpecialtiesTotal Marketing and Specialties$286  353  799  558  Total Marketing and Specialties$476 286 766 799 

Dollars Per Barrel Dollars Per Barrel
Income Before Income TaxesIncome Before Income TaxesIncome Before Income Taxes
U.S.U.S.$1.24  1.09  1.53  0.86  U.S.$2.15 1.24 1.79 1.53 
InternationalInternational3.48  4.81  5.25  3.55  International1.96 3.48 2.09 5.25 
Realized Marketing Fuel Margins*Realized Marketing Fuel Margins*Realized Marketing Fuel Margins*
U.S.U.S.$1.75  1.53  1.92  1.31  U.S.$2.62 1.75 2.31 1.92 
InternationalInternational5.07  6.03  7.04  4.94  International2.89 5.07 3.41 7.04 
* 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 GallonDollars Per Gallon
U.S. Average Wholesale Prices*U.S. Average Wholesale Prices*U.S. Average Wholesale Prices*
GasolineGasoline$1.26  2.32  1.53  2.10  Gasoline$2.44 1.26 2.24 1.53 
DistillatesDistillates1.17  2.20  1.47  2.12  Distillates2.28 1.17 2.14 1.47 
* On third-party branded petroleum product sales, excluding excise taxes.* On third-party branded petroleum product sales, excluding excise taxes.* On third-party branded petroleum product sales, excluding excise taxes.

Thousands of Barrels DailyThousands of Barrels Daily
Marketing Petroleum Products Sales VolumesMarketing Petroleum Products Sales VolumesMarketing Petroleum Products Sales Volumes
GasolineGasoline941  1,240  1,003  1,197  Gasoline1,176 941 1,100 1,003 
DistillatesDistillates847  1,085  942  1,013  Distillates947 847 882 942 
OtherOther15  19  18  18  Other18 15 18 18 
TotalTotal1,803  2,344  1,963  2,228  Total2,141 1,803 2,000 1,963 


The M&S segment purchases for resale and markets refined petroleum products, such as gasoline, distillates and aviation fuels, mainly in the United States and Europe. In addition, this segment includes the manufacturing and marketing of specialty products, such as base oils and lubricants.

Before-tax income from the M&S segment decreased $67increased $190 million in the second quarter of 20202021, and increased $241decreased $33 million in the six-month period of 2020. 2021.

The decreaseincrease in the second quarter of 20202021 was primarily due to lower sales volumeshigher realized U.S. marketing fuel margins driven by decreasedimproved demand for refined petroleum products in key markets, as well as increased equity earnings from Excel Paralubes LLC due to improved base oil margins and specialty products, partially offset by lower selling, general and administrative expenses. volumes.


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The increasedecrease in the six-month period of 20202021 was primarily attributable to higherdriven by lower realized international marketing fuel margins from rising spot prices, decreased margins from chartered marine vessels and lower selling, general and administrative expenses,a benefit received from a legal settlement in the first quarter of 2020.These decreases were partially offset by lowerhigher realized U.S. marketing fuel margins and sales volumes, for refined petroleumas well as increased equity earnings from Excel Paralubes LLC due to improved base oil margins and specialty products driven by decreased demand.volumes.

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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Corporate and Other

Millions of Dollars Millions of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
Three Months Ended
June 30
Six Months Ended
June 30
2020  2019  2020  2019   2021 2020 2021 2020 
Loss Before Income TaxesLoss Before Income TaxesLoss Before Income Taxes
Net interest expenseNet interest expense$(114) (105) (217) (213) Net interest expense$(141)(114)(284)(217)
Corporate overhead and otherCorporate overhead and other(105) (100) (199) (202) Corporate overhead and other(105)(105)(213)(199)
Total Corporate and OtherTotal Corporate and Other$(219) (205) (416) (415) Total Corporate and Other$(246)(219)(497)(416)


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.

Net interest expense increased $9$27 million and $4$67 million, respectively, in the second quarter and six-month period of 2020, respectively,2021. The increase in both periods was primarily driven by lower capitalized interest due to the completion of capital projects and the placement of assets into service, as well as higher average debt principal balances.

Corporate overhead and other remained flat in the second quarter of 2021, and increased $14 million in the six-month period of 2021. The increase in the six-month period was primarily due to higher average debt principal balances, reflecting new debt issuances in the first half of 2020, partially offset by higher capitalized interest related to capital projects under development in our Midstream segment. See Note 9—Debt, in the Notes to Consolidated Financial Statements, for additional information on the new debt issuances.environmental costs.
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CAPITAL RESOURCES AND LIQUIDITY

Financial Indicators

Millions of Dollars,
Except as Indicated
Millions of Dollars,
Except as Indicated
June 30
2020
December 31
2019
June 30
2021
December 31
2020
Cash and cash equivalentsCash and cash equivalents$1,890  1,614  Cash and cash equivalents$2,2072,514 
Short-term debtShort-term debt1,783  547  Short-term debt2,489987 
Total debtTotal debt14,446  11,763  Total debt15,41315,893 
Total equityTotal equity23,295  27,169  Total equity20,60221,523 
Percent of total debt to capital*Percent of total debt to capital*38 %30  Percent of total debt to capital*43%42 
Percent of floating-rate debt to total debtPercent of floating-rate debt to total debt12 % Percent of floating-rate debt to total debt9%12 
* Capital includes total debt and total equity.* Capital includes total debt and total equity.* Capital includes total debt and total equity.


To meet our short- and long-term liquidity requirements, we seekuse a variety of funding sources but rely primarily on cash generated from operating activities and debt financing. Additionally, Phillips 66 Partners has the ability to fund its growth activities through debt and equity financings. During the first six months of 2020,2021, we generated $981 million$2.0 billion of cash from operations, received approximately $2.0 billion in proceeds from two public offeringsincluding a U.S. federal income tax refund of senior unsecured notes, and borrowed $1.0 billion under our new term loan facility.$1.1 billion. We used available cash primarily for capital expenditures and investments of $1.9 billion, repayment of $525$711 million, of maturing debt, and dividend payments on our common stock of $789$788 million, repayment of $550 million of maturing debt, and an additional member loan to an equity affiliate of $245 million. During the first quarter of 2020, we spent $443 million on common stock repurchases, before suspending our share repurchase program in March 2020. During the first six months of 2020,2021, cash and cash equivalents increased $276decreased $307 million to $1.9$2.2 billion.

We believe current cash and cash equivalents and cash generated by operations, together with access to external sources of funds as described below under “Significant Sources of Capital,” will be sufficient to meet our funding requirements in the near and long term, including our capital spending, dividend payments, defined benefit plan contributions, and debt repayments.

Significant Sources of Capital

Operating Activities
During the first six months of 2020,2021, cash generated by operating activities was $981$2,014 million, compared with $1,452$981 million for the first six months of 2019.2020. The decrease in the first six months of 2020, compared with the same period in 2019,increase was primarily due to decreased refinery production and lower refining marginsa U.S. federal income tax refund of $1.1 billion received in the first halfsecond quarter of 2020 driven by significant global economic disruption caused by the COVID-19 pandemic, as well as reduced cash distributions from our equity affiliates, partially offset by higher realized marketing margins and favorable working capital impacts.2021.

Our short- and long-term operating cash flows are highly dependent upon refining and marketing margins, NGL prices and chemical margins, as well as NGL prices.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 recent decline in demand for refined petroleum products has led to a decrease in refining margins. If the global economic disruption associated with the COVID-19 pandemic sustains, we expect refining, marketing and chemical margins, along with transportation volumes, to remain challenged in the near term, all of which could have an unfavorable impact on our future operating cash flows.


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The level and quality of output from our refineries also impact 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 margins and prices. However, the recent decline in demand for refined petroleum products has led to a reduction of our refinery production; and if the global economic disruption associated with the COVID-19 pandemic sustains, we expect the reduced refinery production to continue in the near term, which could have an unfavorable impact on our future operating cash flows.

Equity Affiliate Operating Distributions
Our operating cash flows are also impacted by distribution decisions made by our equity affiliates. During the first six months of 2020,2021, cash from operations included distributions of $820$1,114 million from our equity affiliates, compared with $1,120$820 million during the same period of 2019.2020. We cannot control the amount of future dividends from equity affiliates; therefore, future dividend payments by these equity affiliates are not assured. If the global economic disruption associated with the COVID-19 pandemic sustains, we expect lower distributions from our equity affiliates.

Phillips 66 Partners LPTax Refunds

Unit Issuances
During the first six monthsWe received a U.S. federal income tax refund of 2020, on a settlement-date basis, Phillips 66 Partners generated net proceeds of $2 million from common units issued under its active continuous offering of common units, or at-the-market (ATM) program.

Transfer of Equity Interest
Gray Oak Pipeline, LLC was formed to develop and construct the Gray Oak Pipeline, which transports crude oil from the Permian and Eagle Ford to Texas Gulf Coast destinations that include Corpus Christi and the Sweeny area, including the Phillips 66 Sweeny Refinery, as well as access to the Houston market. Phillips 66 Partners has a consolidated holding company that owns 65% of Gray Oak Pipeline, LLC. In December 2018, a third party exercised its option to acquire a 35% interest in the holding company. Because the holding company’s sole asset was its ownership interest in Gray Oak Pipeline, LLC, which was considered a financial asset, and because certain restrictions were placed on the third party’s ability to transfer or sell its interest in the holding company during the construction of the Gray Oak Pipeline, the legal sale of the 35% interest did not qualify as a sale under GAAP at that time. The Gray Oak Pipeline commenced full operations$1.1 billion in the second quarter of 2020, and the restrictions placed on the co-venturer were lifted on June 30, 2020, resulting in the recognition2021.
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Table of the sale under GAAP. Accordingly, at June 30, 2020, the co-venturer’s 35% interest in the holding company was recharacterized from a long-term obligation to a noncontrolling interest on our consolidated balance sheet. In addition, the premium of $84 million previously paid by the co-venturer in 2019 was recharacterized from a long-term obligation to a gain in our consolidated statement of operations for the three and six months ended June 30, 2020. For the six months ended June 30, 2020, the co-venturer contributed an aggregate of $61 million to the holding company to fund its portion of Gray Oak Pipeline, LLC’s cash calls. Excluding the co-venturer’s 35% interest in the consolidated holding company, Phillips 66 Partners has an effective ownership interest of 42.25% in Gray Oak Pipeline, LLC. See Note 5—Investments, Loans and Long-Term Receivables, in the Notes to Consolidated Financial Statements, for further discussion regarding Phillips 66 Partners’ investment in Gray Oak Pipeline, LLC.Contents

Revolving Credit Facilities and Commercial Paper
At June 30, 2020,2021, borrowings of $215$15 million were outstanding and $3$1 million in letters of credit had been drawn under Phillips 66 Partners’ $750 million revolving credit facility.facility, compared with outstanding borrowings of $415 million and $1 million in letters of credit drawn under the facility at December 31, 2020. At both June 30, 2021, and December 31, 2020, no amount had been drawn under Phillips 66’s $5 billion revolving credit facility or uncommitted $5 billion commercial paper program.
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Other Debt Issuances and Financings
On June 10, 2020, Phillips 66 closed its public offering of $1 billion aggregate principal amount of senior unsecured notes consisting of:

$150 million aggregate principal amount of 3.850% Senior Notes due 2025.
$850 million aggregate principal amount of 2.150% Senior Notes due 2030.

Term Loan Agreement
On April 9, 2020,6, 2021, Phillips 66 closed its public offering of $1 billion aggregate principal amount of senior unsecured notes consisting of:

$500 million aggregate principal amount of 3.700% Senior Notes due 2023.
$500 million aggregate principal amount of 3.850% Senior Notes due 2025.

Interest on the Senior Notes due 2023 is payable semiannually on April 6 and October 6 of each year, commencing on October 6, 2020. The Senior Notes due 2025 issued on June 10, 2020, constitute a further issuance of the Senior Notes due 2025 originally issued on April 9, 2020. The $650 million in aggregate principal amount of Senior Notes due 2025 is treated as a single class of debt securities. Interest on the Senior Notes due 2025 is payable semiannually on April 9 and October 9 of each year, commencing on October 9, 2020. Interest on the Senior Notes due 2030 is payable semiannually on June 15 and December 15 of each year, commencing on December 15, 2020.

Proceeds received from the public offerings of senior unsecured notes on June 10, 2020, and April 9, 2020, were $1,008 million exclusive of accrued interest received, and $993 million, respectively, net of underwriters’ discounts or premiums and commissions, as well as debt issuance costs. These proceeds are being used for general corporate purposes.

On March 19, 2020, Phillips 66Partners entered into a $1 billion 364-day delayed draw$450 million term loan agreement (the Facility) and borrowed $1 billion under the Facility shortly thereafter. Onfull amount. The term loan agreement has a maturity date of April 6, 2020, Phillips 66 increased5, 2022, and the size of the Facilityoutstanding borrowings can be repaid at any time and from time to $2 billion, with $1 billion of capacity remaining undrawn at June 30, 2020. In June 2020, the Facility was amended to extend the commitment period to September 19, 2020.time, in whole or in part, without premium or penalty. Borrowings under the Facility bear interest at a floating rate based on either thea Eurodollar rate or thea reference rate, plus a margin determined by the credit rating of Phillips 66’s senior unsecured long-term debt.0.875%. Proceeds were primarily used to repay amounts borrowed under Phillips 66 is using the proceeds from the debt issuance for general corporate purposes.Partners’ $750 million revolving credit facility.




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Off-Balance Sheet ArrangementsMarketing and Specialties

Lease Residual Value Guarantees
Under the operating lease agreement on our headquarters facility in Houston, Texas, we have a residual value guarantee with a maximum future exposure of $554 million at June 30, 2020. The operating lease term ends in June 2021 and provides us the option, at the end of the lease term, to request to renew the lease, purchase the facility or assist the lessor in marketing it for resale. We also have residual value guarantees associated with railcar and airplane leases with maximum potential future payments totaling $351 million at June 30, 2020, which have remaining terms of up to four years.
 Three Months Ended
June 30
Six Months Ended
June 30
2021 2020 2021 2020 
Millions of Dollars
Income Before Income Taxes
Marketing and Other$389 255 600 726 
Specialties87 31 166 73 
Total Marketing and Specialties$476 286 766 799 

Dakota Access, LLC (Dakota Access) and Energy Transfer Crude Oil Company, LLC (ETCO)
 Dollars Per Barrel
Income Before Income Taxes
U.S.$2.15 1.24 1.79 1.53 
International1.96 3.48 2.09 5.25 
Realized Marketing Fuel Margins*
U.S.$2.62 1.75 2.31 1.92 
International2.89 5.07 3.41 7.04 
In March 2019,* See the “Non-GAAP Reconciliations” section for a wholly owned subsidiaryreconciliation of Dakota Access closed an offering of $2.5 billion aggregate principal amount of unsecured senior notes, consisting 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$2.44 1.26 2.24 1.53 
Distillates2.28 1.17 2.14 1.47 
* On third-party branded petroleum product sales, excluding excise taxes.

Thousands of Barrels Daily
Marketing Petroleum Products Sales Volumes
Gasoline1,176 941 1,100 1,003 
Distillates947 847 882 942 
Other18 15 18 18 
Total2,141 1,803 2,000 1,963 


$650 million aggregate principal amount
The M&S segment purchases for resale and markets refined petroleum products, such as gasoline, distillates and aviation fuels, mainly in the United States and Europe. In addition, this segment includes the manufacturing and marketing of 3.625% Senior Notes due 2022.
$1.0 billion aggregate principal amount of 3.900% Senior Notes due 2024.
$850 million aggregate principal amount of 4.625% Senior Notes due 2029.specialty products, such as base oils and lubricants.

Dakota Access and ETCO have guaranteed repayment ofBefore-tax income from the notes. In addition, Phillips 66 Partners and its co-venturers in Dakota Access 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 judgmentM&S segment increased $190 million in the ongoing litigation related to an easement granted bysecond quarter of 2021, and decreased $33 million in the U.S. Army Corpssix-month period of Engineers (USACE) to allow the pipeline to be constructed under Lake Oahe in North Dakota. Contributions may be required if Dakota Access determines that the issues included in any such final judgment cannot be remediated and Dakota Access has or is projected to have insufficient funds to satisfy repayment of the notes. If Dakota Access undertakes remediation to cure issues raised in a final judgment, contributions may be required if any series of the notes become due, whether by acceleration or at maturity, during such time, to the extent Dakota Access has or is projected to have insufficient funds to pay such amounts. At June 30, 2020, Phillips 66 Partners’ share of the maximum potential equity contributions under the CECU was approximately $631 million.2021.

In March 2020,The increase in the court presiding over this litigation ordered the USACEsecond quarter of 2021 was primarily due to prepare an Environmental Impact Statement (EIS),higher realized U.S. marketing fuel margins driven by improved demand for refined petroleum products in key markets, as well as increased equity earnings from Excel Paralubes LLC due to improved base oil margins and requested additional information to enable a decision on whether the Dakota Access Pipeline should be shut down while the EIS is being prepared. On July 6, 2020, the court ordered the Dakota Access Pipeline to be shut down and emptied of crude oil by August 5, 2020, and that the pipeline should remain shut down pending the preparation of the EIS by the USACE, which the USACE has indicated is expected to take approximately 13 months. Dakota Access filed an appeal and a request for a stay of the order. On July 14, 2020, an appeals court granted a temporary stay of the lower court’s order directing the pipeline to be shut down and emptied of crude oil. The appeals court has not yet ruled on the motion for a stay during the appeals process. In addition to the potential obligations under the CECU, if the pipeline is required to cease operations pending the preparation of the EIS, and should Dakota Access and ETCO not have sufficient funds to pay ongoing expenses, Phillips 66 Partners also could be asked to support its share of the ongoing expenses, including scheduled interest payments on the notes of approximately $25 million annually.

Gray Oak Pipeline, LLC
Gray Oak Pipeline, LLC has a third-party term loan facility with a borrowing capacity of $1,379 million, inclusive of accrued interest. Borrowings under the facility are due on June 3, 2022.  Phillips 66 Partners and its co-venturers provided a guarantee through an equity contribution agreement requiring proportionate equity contributions to Gray Oak Pipeline, LLC up to the total outstanding loan amount, plus any additional accrued interest and associated fees, if Gray Oak Pipeline, LLC defaults on certain of its obligations thereunder.  At June 30, 2020, the term loan facility was fully utilized by Gray Oak Pipeline, LLC, and Phillips 66 Partners’ 42.25% proportionate exposure under the equity contribution agreement was $583 million. volumes.


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Other Guarantees
At June 30, 2020, we had other guarantees outstanding for our portionThe decrease in the six-month period of certain joint venture debt obligations2021 was primarily driven by lower realized international marketing fuel margins from rising spot prices, decreased margins from chartered marine vessels and purchase obligations, which have remaining termsa benefit received from a legal settlement in the first quarter of up2020.These decreases were partially offset by higher realized U.S. marketing fuel margins and sales volumes, as well as increased equity earnings from Excel Paralubes LLC due to eight years. The maximum potential amount of future payments to third parties under these guarantees was approximately $155 million. Payment would be required if a joint venture defaults on its obligations.improved base oil margins and volumes.

See Note 10—Guarantees, in the Notes to Consolidated Financial Statements,“Executive Overview and Business Environment” section for additional information on our guarantees.marketing fuel margins and other market factors impacting this quarter’s results.

Capital Requirements
Corporate and Other

Capital Expenditures
 Millions of Dollars
 Three Months Ended
June 30
Six Months Ended
June 30
 2021 2020 2021 2020 
Loss Before Income Taxes
Net interest expense$(141)(114)(284)(217)
Corporate overhead and other(105)(105)(213)(199)
Total Corporate and Other$(246)(219)(497)(416)


Net interest expense consists of interest and Investmentsfinancing 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.
For information about
Net interest expense increased $27 million and $67 million, respectively, in the second quarter and six-month period of 2021. The increase in both periods was primarily driven by lower capitalized interest due to the completion of capital projects and the placement of assets into service, as well as higher average debt principal balances.

Corporate overhead and other remained flat in the second quarter of 2021, and increased $14 million in the six-month period of 2021. The increase in the six-month period was primarily due to higher environmental costs.
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CAPITAL RESOURCES AND LIQUIDITY

Financial Indicators

Millions of Dollars,
Except as Indicated
June 30
2021
December 31
2020
Cash and cash equivalents$2,2072,514 
Short-term debt2,489987 
Total debt15,41315,893 
Total equity20,60221,523 
Percent of total debt to capital*43%42 
Percent of floating-rate debt to total debt9%12 
* 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 six months of 2021, we generated $2.0 billion of cash from operations, including a U.S. federal income tax refund of $1.1 billion. We used available cash primarily for capital expenditures and investments seeof $711 million, dividend payments on our common stock of $788 million, repayment of $550 million of maturing debt, and an additional member loan to an equity affiliate of $245 million. During the “Capital Spending” section below.first six months of 2021, cash and cash equivalents decreased $307 million to $2.2 billion.

Debt Financing
Our total debt balance at June 30, 2020, and December 31, 2019, was $14.4 billion and $11.8 billion, respectively. Our total debt-to-capital ratio was 38% and 30% at June 30, 2020, and December 31, 2019, respectively.Significant Sources of Capital

In April 2020, Phillips 66 repaidOperating Activities
During the $300first six months of 2021, cash generated by operating activities was $2,014 million, outstanding principal balancecompared with $981 million for the first six months of its floating-rate notes2020. The increase was primarily due April 2020 andto a U.S. federal income tax refund of $1.1 billion received in the $200 million outstanding principal balancesecond quarter of its term loan facility due April 2020. Also in April 2020, Phillips 66 Partners repaid the $25 million outstanding principal balance of its tax-exempt bonds due April 2020.2021.

Dividends
On May 6, 2020,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 Board of Directors declaredindustry 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 quarterlycorresponding change in our operating cash dividend of $0.90 per common share. The dividend was paid on June 1, 2020, to shareholders of record at the close of business on May 18, 2020. On July 8, 2020, our Board of Directors declared a quarterly cash dividend of $0.90 per common share. This dividend is payable on September 1, 2020, to shareholders of record at the close of business on August 18, 2020. flows.

Share Repurchases
Since July 2012,The level and quality of output from our Board of Directors has, at various times, authorized repurchasesrefineries also impact 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 outstanding common stock underrefineries, and any variability in their operations typically has not been as significant to cash flows as that caused by margins and prices.

Equity Affiliate Operating Distributions
Our operating cash flows are also impacted by distribution decisions made by our share repurchase programs, which aggregate toequity affiliates. During the first six months of 2021, cash from operations included distributions of $1,114 million from our equity affiliates, compared with $820 million during the same period of 2020. We cannot control the amount of future dividends from equity affiliates; therefore, future dividend payments by these equity affiliates are not assured.

Tax Refunds
We received a totalU.S. federal income tax refund of $15 billion. The authorizations do not have expiration dates. The share repurchases are expected to be funded primarily through available cash. The shares under these authorizations are repurchased from time to time$1.1 billion in the open market at our discretion, subject to market conditions and other factors, and in accordance with applicable regulatory requirements. Since the inceptionsecond quarter of our share repurchase programs in 2012 through March 17, 2020, we have repurchased 159 million shares at an aggregate cost of $12.5 billion. Shares of stock repurchased are held as treasury shares. We suspended share repurchases in mid-March 2020 to preserve liquidity in response to the economic effects of the COVID-19 pandemic and other factors.
2021.
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Capital SpendingRevolving Credit Facilities and Commercial Paper
At June 30, 2021, borrowings of $15 million were outstanding and $1 million in letters of credit had been drawn under Phillips 66 Partners’ $750 million revolving credit facility, compared with outstanding borrowings of $415 million and $1 million in letters of credit drawn under the facility at December 31, 2020. At both June 30, 2021, and December 31, 2020, no amount had been drawn under Phillips 66’s $5 billion revolving credit facility or uncommitted $5 billion commercial paper program.

Our capital expendituresTerm Loan Agreement
On April 6, 2021, Phillips 66 Partners entered into a $450 million term loan agreement and investments represent consolidated capital spending. Our adjusted capital spending isborrowed the full amount. The term loan agreement has a non-GAAP financial measure that demonstrates our net sharematurity date of capital spending,April 5, 2022, and reflects an adjustment for the portionoutstanding borrowings can be repaid at any time and from time to time, in whole or in part, without premium or penalty. Borrowings bear interest at a floating rate based on either a Eurodollar rate or a reference rate, plus a margin of our consolidated capital spending funded by certain joint venture partners.0.875%. Proceeds were primarily used to repay amounts borrowed under Phillips 66 Partners’ $750 million revolving credit facility.

 Millions of Dollars
 Six Months Ended
June 30
 2020  2019  
Capital Expenditures and Investments
Midstream$1,238  1,200  
Chemicals—  —  
Refining409  391  
Marketing and Specialties111  42  
Corporate and Other104  95  
Total Capital Expenditures and Investments1,862  1,728  
Less: capital spending funded by certain joint venture partners*61  422  
Adjusted Capital Spending$1,801  1,306  
Selected Equity Affiliates**
DCP Midstream$90  278  
CPChem139  175  
WRB71  81  
$300  534  
* Included in the Midstream segment.
** Our share of joint ventures’ self-funded capital spending.


Midstream
During the first six months of 2020, capital spending in our Midstream segment included:

Continued development of additional Gulf Coast fractionation capacity.
Cash contributions to our and Phillips 66 Partners’ joint ventures to develop and construct the Liberty and Red Oak pipeline systems.
Cash contributions to Phillips 66 Partners’ Gray Oak Pipeline and South Texas Gateway Terminal for their development activities.
Capacity expansion on Phillips 66 Partners’ Sweeny to Pasadena refined petroleum product pipeline.
Construction activities on Phillips 66 Partners’ new ethane pipeline from Clemens Caverns to petrochemical facilities in Gregory, Texas (C2G Pipeline).
Construction activities to increase storage capacity at our crude oil and refined petroleum product terminal located near Beaumont, Texas.
Other reliability, return and maintenance projects.

On March 2, 2020, Phillips 66 Partners closed a transaction to acquire our 50% interest in Liberty Pipeline LLC for $75 million. The development and construction of our Red Oak Pipeline system and Sweeny Frac 4, as well as Phillips 66 Partners’ Liberty Pipeline system projects have been deferred as a result of the current challenging business environment.


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During the first six months of 2020, DCP Midstream’s self-funded capital expenditures and investments were $179 million on a 100% basis. Capital spending during this period was primarily for expansion projects, including the construction of the Latham II offload facilities and the Cheyenne Connector, and investments in the Sand Hills and Southern Hills joint ventures, as well as maintenance capital expenditures for existing assets. In April 2020, DCP Midstream announced capital and cost reduction plans, including a 75% growth capital reduction. We expect that DCP Midstream’s capital program will continue to be self-funded for the remainder of 2020.

Chemicals
During the first six months of 2020, CPChem had a self-funded capital program. During this period, on a 100% basis, CPChem’s capital expenditures and investments were $277 million. The capital spending was primarily for the continued development of its second U.S. Gulf Coast petrochemical project and debottlenecking projects on existing assets. We expect CPChem to continue self-funding its capital program for the remainder of 2020.

Refining
Capital spending for the Refining segment during the first six months of 2020 was primarily for refinery upgrade projects to enhance the yield of high value products, renewable diesel projects, improvements to the operating integrity of key processing units, and safety-related projects. Our equity affiliates in the Refining segment had self-funded capital programs during the first six months of 2020, and we expect them to continue self-funding their capital programs for the remainder of 2020.

Major construction activities included:

Installation and startup of facilities to improve product value at the Sweeny Refinery.
Installation of facilities to improve product value at the Ponca City and Bayway refineries.
Installation of facilities to produce biofuels at the Humber Refinery.

Marketing and Specialties

 Three Months Ended
June 30
Six Months Ended
June 30
2021 2020 2021 2020 
Millions of Dollars
Income Before Income Taxes
Marketing and Other$389 255 600 726 
Specialties87 31 166 73 
Total Marketing and Specialties$476 286 766 799 

 Dollars Per Barrel
Income Before Income Taxes
U.S.$2.15 1.24 1.79 1.53 
International1.96 3.48 2.09 5.25 
Realized Marketing Fuel Margins*
U.S.$2.62 1.75 2.31 1.92 
International2.89 5.07 3.41 7.04 
* 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$2.44 1.26 2.24 1.53 
Distillates2.28 1.17 2.14 1.47 
* On third-party branded petroleum product sales, excluding excise taxes.

Thousands of Barrels Daily
Marketing Petroleum Products Sales Volumes
Gasoline1,176 941 1,100 1,003 
Distillates947 847 882 942 
Other18 15 18 18 
Total2,141 1,803 2,000 1,963 


The M&S segment purchases for resale and markets refined petroleum products, such as gasoline, distillates and aviation fuels, mainly in the United States and Europe. In addition, this segment includes the manufacturing and marketing of specialty products, such as base oils and lubricants.

Before-tax income from the M&S segment increased $190 million in the second quarter of 2021, and decreased $33 million in the six-month period of 2021.

The increase in the second quarter of 2021 was primarily due to higher realized U.S. marketing fuel margins driven by improved demand for refined petroleum products in key markets, as well as increased equity earnings from Excel Paralubes LLC due to improved base oil margins and volumes.


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The decrease in the six-month period of 2021 was primarily driven by lower realized international marketing fuel margins from rising spot prices, decreased margins from chartered marine vessels and a benefit received from a legal settlement in the first quarter of 2020.These decreases were partially offset by higher realized U.S. marketing fuel margins and sales volumes, as well as increased equity earnings from Excel Paralubes LLC due to improved base oil margins and volumes.

See the “Executive Overview and Business Environment” section for information on marketing fuel margins and other market factors impacting this quarter’s results.


Corporate and Other

 Millions of Dollars
 Three Months Ended
June 30
Six Months Ended
June 30
 2021 2020 2021 2020 
Loss Before Income Taxes
Net interest expense$(141)(114)(284)(217)
Corporate overhead and other(105)(105)(213)(199)
Total Corporate and Other$(246)(219)(497)(416)


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.

Net interest expense increased $27 million and $67 million, respectively, in the second quarter and six-month period of 2021. The increase in both periods was primarily driven by lower capitalized interest due to the completion of capital projects and the placement of assets into service, as well as higher average debt principal balances.

Corporate overhead and other remained flat in the second quarter of 2021, and increased $14 million in the six-month period of 2021. The increase in the six-month period was primarily due to higher environmental costs.
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CAPITAL RESOURCES AND LIQUIDITY

Financial Indicators

Millions of Dollars,
Except as Indicated
June 30
2021
December 31
2020
Cash and cash equivalents$2,2072,514 
Short-term debt2,489987 
Total debt15,41315,893 
Total equity20,60221,523 
Percent of total debt to capital*43%42 
Percent of floating-rate debt to total debt9%12 
* 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 six months of 2021, we generated $2.0 billion of cash from operations, including a U.S. federal income tax refund of $1.1 billion. We used available cash primarily for capital expenditures and investments of $711 million, dividend payments on our common stock of $788 million, repayment of $550 million of maturing debt, and an additional member loan to an equity affiliate of $245 million. During the first six months of 2021, cash and cash equivalents decreased $307 million to $2.2 billion.

Significant Sources of Capital

Operating Activities
During the first six months of 2021, cash generated by operating activities was $2,014 million, compared with $981 million for the first six months of 2020. The increase was primarily due to a U.S. federal income tax refund of $1.1 billion received in the second quarter of 2021.

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 impact 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 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 six months of 2021, cash from operations included distributions of $1,114 million from our equity affiliates, compared with $820 million during the same period of 2020. We cannot control the amount of future dividends from equity affiliates; therefore, future dividend payments by these equity affiliates are not assured.

Tax Refunds
We received a U.S. federal income tax refund of $1.1 billion in the second quarter of 2021.
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Revolving Credit Facilities and Commercial Paper
At June 30, 2021, borrowings of $15 million were outstanding and $1 million in letters of credit had been drawn under Phillips 66 Partners’ $750 million revolving credit facility, compared with outstanding borrowings of $415 million and $1 million in letters of credit drawn under the facility at December 31, 2020. At both June 30, 2021, and December 31, 2020, no amount had been drawn under Phillips 66’s $5 billion revolving credit facility or uncommitted $5 billion commercial paper program.

Term Loan Agreement
On April 6, 2021, Phillips 66 Partners entered into a $450 million term loan agreement and borrowed the full amount. The term loan agreement has a maturity date of April 5, 2022, and the outstanding borrowings can be repaid at any time and from time to time, in whole or in part, without premium or penalty. Borrowings bear interest at a floating rate based on either a Eurodollar rate or a reference rate, plus a margin of 0.875%. Proceeds were primarily used to repay amounts borrowed under Phillips 66 Partners’ $750 million revolving credit facility.




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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 June 30, 2021. We also have residual value guarantees associated with railcar and airplane leases with maximum potential future exposures totaling $209 million. These leases have remaining terms of up to nine years.

Dakota Access, LLC (Dakota Access) and Energy Transfer Crude Oil Company, LLC (ETCO)
In 2020, the trial court presiding over litigation regarding the Dakota Access Pipeline ordered the U.S. Army Corps of Engineers (USACE) to prepare an Environmental Impact Statement (EIS) relating to an easement under Lake Oahe in North Dakota and later vacated the easement. Although the easement has been vacated, the USACE has indicated that it will not take action to stop pipeline operations while it proceeds with the EIS, which is expected to be completed in 2022. In May 2021, the court denied a request for an injunction to shut down the pipeline while the EIS is being prepared and in June 2021, dismissed the litigation. It is possible that the litigation could be reopened or new litigation challenging the EIS, once completed, could be filed.

Dakota Access and ETCO have guaranteed repayment of $2.5 billion aggregate principal amount of senior unsecured notes issued by a wholly owned subsidiary of Dakota Access. In addition, Phillips 66 Partners and its co-venturers in Dakota Access 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 in certain circumstances relating to the litigation described above. At June 30, 2021, Phillips 66 Partners’ share of the maximum potential equity contributions under the CECU was approximately $631 million.

If the pipeline is required to cease operations, and should Dakota Access and ETCO not have sufficient funds to pay ongoing expenses, Phillips 66 Partners also could be required to support its share of the ongoing expenses, including scheduled interest payments on the notes of approximately $25 million annually, in addition to the potential obligations under the CECU.

See Note 10—Guarantees, in the Notes to Consolidated Financial Statements, for additional information on 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 total debt balance at June 30, 2021, and December 31, 2020, was $15.4 billion and $15.9 billion, respectively. Our total debt-to-capital ratio was 43% and 42% at June 30, 2021, and December 31, 2020, respectively.

In April 2021, Phillips 66 Partners repaid $50 million of its tax-exempt bonds upon maturity.

In February 2021, Phillips 66 repaid $500 million outstanding principal balance of its floating-rate senior notes due February 2021.

Joint Venture Loans
We and our co-venturer provided member loans to WRB. At June 30, 2021, our 50% share of the outstanding member loan balance, including accrued interest, was $525 million. The need for additional loans to WRB in the remainder of 2021, as well as WRB’s repayment schedule, will depend on market conditions.

Dividends
On May 12, 2021, our board of directors declared a quarterly cash dividend of $0.90 per common share. The dividend was paid on June 1, 2021, to shareholders of record as of the close of business on May 24, 2021. On July 14, 2021, our board of directors declared a quarterly cash dividend of $0.90 per common share. This dividend is payable on September 1, 2021, to shareholders of record as of the close of business on August 18, 2021.

Share Repurchases
Since July 2012, our board of directors has authorized an aggregate of $15 billion of repurchases of our outstanding common stock. The authorizations do not have expiration dates. The share repurchases are expected to be funded primarily through available cash. We are not obligated to repurchase any shares of common stock pursuant to these authorizations and may commence, suspend or terminate repurchases at any time. Since the inception of our share repurchase program in 2012, we have repurchased 159 million shares at an aggregate cost of $12.5 billion. Shares of stock repurchased are held as treasury shares. We suspended share repurchases in mid-March 2020 to preserve liquidity in response to the global economic disruption caused by the COVID-19 pandemic.
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Capital Spending

Our capital expenditures and investments represent consolidated capital spending. Our adjusted capital spending is a non-GAAP financial measure that demonstrates our net share of capital spending, and reflects an adjustment for the portion of our consolidated capital spending funded by a joint venture partner.

 Millions of Dollars
 Six Months Ended
June 30
 2021 2020 
Capital Expenditures and Investments
Midstream$241 1,238 
Chemicals — 
Refining370 409 
Marketing and Specialties44 111 
Corporate and Other56 104 
Total Capital Expenditures and Investments711 1,862 
Less: capital spending funded by a joint venture partner* 61 
Adjusted Capital Spending$711 1,801 
Selected Equity Affiliates**
DCP Midstream$21 90 
CPChem151 139 
WRB106 71 
$278 300 
* Included in the Midstream segment.
** Our share of joint venture’s capital spending.


Midstream
During the first six months of 2021, capital spending in our Midstream segment included:

Construction activities on Phillips 66 Partners’ C2G Pipeline, a new 16-inch ethane pipeline that connects Phillips 66 Partners’ Clemens Caverns storage facility to petrochemical facilities in Gregory, Texas, near Corpus Christi, Texas.

Construction activities on a new 35-mile, 12-inch hydrogen gas pipeline connecting Alliance Refinery to hydrogen gas sources.

Contributions to Dakota Access by Phillips 66 Partners for a pipeline optimization project.

Investment in a renewable feedstock processing plant.

Contributions by Phillips 66 Partners to complete the South Texas Gateway Terminal development activities.

Continued development of additional Gulf Coast fractionation capacity at the Sweeny Hub.

Spending associated with other return, reliability, and maintenance projects in our Transportation and NGL businesses.


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Chemicals
During the first six months of 2021, on a 100% basis, CPChem’s capital expenditures and investments were $301 million. The capital spending was primarily for optimization, debottlenecking and sustaining 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 2021.

Refining
Capital spending for the Refining segment during the first six months of 2021 was primarily for refinery upgrade projects to enhance the yield of high-value products, renewable diesel projects, improvements to the operating integrity of key processing units, and safety-related projects.

In the second quarter of 2021, we started up facilities to improve product value at the Ponca City Refinery and facilities to provide flexibility to produce renewable diesel at the San Francisco Refinery. Other major construction activities included installation of facilities to improve product value at the jointly owned Wood River Refinery.

Marketing and Specialties
Capital spending for the M&S segment during the first six months of 20202021 was primarily for an additional investment in the U.S. West Coasta retail marketing joint venture in the Central region and the acquisition, development and enhancement of retail sites in Europe.

Corporate and Other
Capital spending for Corporate and Other during the first six months of 20202021 was primarily for information technology.technology and facilities.



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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 less than certain.uncertain.

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. 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 the 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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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 of these 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 20192020 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 six months ended June 30, 2021 and 2020, we incurred expenses of $422 million and $147 million, respectively, 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 operations. Our jointly owned refineries also incurred expenses associated with the purchase of RINs in the open market, of which our share was $178 million and $50 million for the six months ended June 30, 2021 and 2020, respectively. These expenses are included in the “Equity in earnings of affiliates” line item on our consolidated statement of operations. The amount of these expenses and fluctuations between periods is primarily driven by the market price of RINs, refinery production and blending activities.

We occasionally receive requests for information or notices of potential liability from the U.S. Environmental Protection Agency (EPA)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 June 30, 2021, and December 31, 2019, we reported that2020, we had been notified of potential liability under CERCLA and comparable state laws at 2725 sites within the United States. In the second quarter of 2020, we were notified of two Superfund sites that were deemed resolved and closed, accordingly, leaving 25 unresolved sites with potential liability at June 30, 2020.

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 notcould 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. We continue to monitor legislative and regulatory actions and legal proceedings globally relating to GHG emissions for potential impacts on our operations.

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 20192020 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 throughout our operations.

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GUARANTOR FINANCIAL INFORMATION
At June 30, 2021, Phillips 66 had $10.8 billion of senior unsecured notes outstanding guaranteed by Phillips 66 Company, a direct, wholly owned operating subsidiary of Phillips 66. 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. The guarantees (1) are unsecured obligations of Phillips 66 Company, (2) rank equally with all of Phillips 66 Company’s other unsecured and unsubordinated indebtedness, and (3) are full and unconditional.

Summarized financial information of Phillips 66 and Phillips 66 Company (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.

The summarized results of operations for the six months ended June 30, 2021, and the summarized financial position at June 30, 2021, and December 31, 2020, for the Obligor Group on a combined basis were:


Summarized Combined Statement of OperationsMillions of Dollars
Six Months Ended June 30, 2021
Sales and other operating revenues$37,273
Revenues and other income—non-guarantor subsidiaries2,371
Purchased crude oil and products—third parties23,836
Purchased crude oil and products—related parties5,710
Purchased crude oil and products—non-guarantor subsidiaries7,921
Loss before income taxes(639)
Net loss(494)


Millions of Dollars
Summarized Combined Balance SheetJune 30
2021
December 31
2020
Accounts and notes receivable—third parties$4,109 4,060 
Accounts and notes receivable—related parties1,389 804 
Due from non-guarantor subsidiaries, current604 288 
Total current assets11,538 8,965 
Investments and long-term receivables9,536 9,229 
Net properties, plants and equipment12,823 12,815 
Goodwill1,047 1,047 
Due from non-guarantor subsidiaries, noncurrent6,148 6,173 
Other assets associated with non-guarantor subsidiaries2,737 2,870 
Total noncurrent assets34,132 34,034 
Total assets45,670 42,999 
Due to non-guarantor subsidiaries, current$3,042 2,203 
Total current liabilities12,599 7,938 
Long-term debt9,327 11,330 
Due to non-guarantor subsidiaries, noncurrent9,965 9,316 
Total noncurrent liabilities24,828 26,044 
Total liabilities37,427 33,982 
Total equity8,243 9,017 
Total liabilities and equity45,670 42,999 
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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) purchase 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 “Business“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)loss before income taxes to realized refining margins:
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Millions of Dollars, Except as Indicated
Realized Refining MarginsAtlantic Basin/
Europe
Gulf
Coast
Central
Corridor
West
Coast
Worldwide
Three Months Ended June 30, 2020
Loss before income taxes$(227) (365) (104) (182) (878) 
Plus:
Taxes other than income taxes15  25  14  22  76  
Depreciation, amortization and impairments49  75  33  63  220  
Selling, general and administrative expenses12  10    38  
Operating expenses190  277  120  216  803  
Equity in (earnings) losses of affiliates (1) 79  —  81  
Other segment expense, net —     
Proportional share of refining gross margins contributed by equity affiliates16  —  92  —  108  
Special items:
Lower-of-cost-or-market inventory adjustments—  —  (35) —  (35) 
Realized refining margins$61  21  209  129  420  
Total processed inputs (thousands of barrels)
39,121  61,032  20,778  25,737  146,668  
Adjusted total processed inputs (thousands of barrels)*
39,121  61,032  36,067  25,737  161,957  
Loss before income taxes per barrel (dollars per barrel)**
$(5.80) (5.98) (5.01) (7.07) (5.99) 
Realized refining margins (dollars per barrel)***
1.53  0.36  5.78  5.05  2.60  
Three Months Ended June 30, 2019
Income (loss) before income taxes$258  222  520  (17) 983  
Plus:
Taxes other than income taxes11  16  10  21  58  
Depreciation, amortization and impairments49  68  34  63  214  
Selling, general and administrative expenses10     33  
Operating expenses201  322  134  249  906  
Equity in (earnings) losses of affiliates  (133) —  (128) 
Other segment (income) expense, net (5)    
Proportional share of refining gross margins contributed by equity affiliates19  —  298  —  317  
Realized refining margins$555  633  874  325  2,387  
Total processed inputs (thousands of barrels)
51,172  77,186  26,244  32,697  187,299  
Adjusted total processed inputs (thousands of barrels)*
51,172  77,186  48,932  32,697  209,987  
Income (loss) before income taxes per barrel (dollars per barrel)**
$5.04  2.88  19.81  (0.52) 5.25  
Realized refining margins (dollars per barrel)***
10.85  8.20  17.84  9.94  11.37  
    * 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.




Millions of Dollars, Except as Indicated
Realized Refining MarginsAtlantic Basin/
Europe
Gulf
Coast
Central
Corridor
West
Coast
Worldwide
Three Months Ended June 30, 2021
Loss before income taxes$(110)(264)(82)(273)(729)
Plus:
Taxes other than income taxes18 25 11 22 76 
Depreciation, amortization and impairments52 77 34 57 220 
Selling, general and administrative expenses18 14 7 10 49 
Operating expenses217 299 125 281 922 
Equity in losses of affiliates2  65  67 
Other segment income, net(8)(6)(8)(2)(24)
Proportional share of refining gross margins contributed by equity affiliates42  125  167 
Realized refining margins$231 145 277 95 748 
Total processed inputs (thousands of barrels)
49,979 69,364 23,466 28,158 170,967 
Adjusted total processed inputs (thousands of barrels)*
49,979 69,364 43,189 28,158 190,690 
Loss before income taxes per barrel (dollars per barrel)**
$(2.20)(3.81)(3.49)(9.70)(4.26)
Realized refining margins (dollars per barrel)***
4.63 2.10 6.40 3.37 3.92 
Three Months Ended June 30, 2020
Loss before income taxes$(227)(365)(104)(182)(878)
Plus:
Taxes other than income taxes15 25 14 22 76 
Depreciation, amortization and impairments49 75 33 63 220 
Selling, general and administrative expenses12 10 38 
Operating expenses190 277 120 216 803 
Equity in (earnings) losses of affiliates(1)79 — 81 
Other segment expense, net— 
Proportional share of refining gross margins contributed by equity affiliates16 — 92 — 108 
Special items:
Lower-of-cost-or-market inventory adjustments— — (35)— (35)
Realized refining margins$61 21 209 129 420 
Total processed inputs (thousands of barrels)
39,121 61,032 20,778 25,737 146,668 
Adjusted total processed inputs (thousands of barrels)*
39,121 61,032 36,067 25,737 161,957 
Loss before income taxes per barrel (dollars per barrel)**
$(5.80)(5.98)(5.01)(7.07)(5.99)
Realized refining margins (dollars per barrel)***
1.53 0.36 5.78 5.05 2.60 
    * Adjusted total processed inputs include our proportional share of processed inputs of an equity affiliate.
  ** Loss before income taxes divided by total processed inputs.
*** Realized refining margins per barrel, as presented, are calculated using the underlying realized refining margin amounts, in dollars, divided by adjusted total processed inputs, in barrels. As such, recalculated per barrel amounts using the rounded margins and barrels presented may differ from the presented per barrel amounts.
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Millions of Dollars, Except as IndicatedMillions of Dollars, Except as Indicated
Realized Refining MarginsRealized Refining MarginsAtlantic Basin/ EuropeGulf CoastCentral CorridorWest CoastWorldwideRealized Refining MarginsAtlantic Basin/
Europe
Gulf
Coast
Central
Corridor
West
Coast
Worldwide
Six Months Ended June 30, 2020
Six Months Ended June 30, 2021Six Months Ended June 30, 2021
Loss before income taxesLoss before income taxes$(864) (1,208) (331) (736) (3,139) Loss before income taxes$(263)(517)(330)(659)(1,769)
Plus:Plus:Plus:
Taxes other than income taxesTaxes other than income taxes34  62  31  53  180  Taxes other than income taxes38 52 26 45 161 
Depreciation, amortization and impairmentsDepreciation, amortization and impairments541  816  502  427  2,286  Depreciation, amortization and impairments104 154 68 111 437 
Selling, general and administrative expensesSelling, general and administrative expenses25  17  13  19  74  Selling, general and administrative expenses32 24 14 21 91 
Operating expensesOperating expenses384  769  256  499  1,908  Operating expenses447 620 330 663 2,060 
Equity in (earnings) losses of affiliates (2) 130  —  133  
Other segment expense, net  —    
Equity in losses of affiliatesEquity in losses of affiliates4 3 182  189 
Other segment income, netOther segment income, net(8)(6)(10) (24)
Proportional share of refining gross margins contributed by equity affiliatesProportional share of refining gross margins contributed by equity affiliates32  —  205  —  237  Proportional share of refining gross margins contributed by equity affiliates85  211  296 
Realized refining marginsRealized refining margins$158  455  806  264  1,683  Realized refining margins$439 330 491 181 1,441 
Total processed inputs (thousands of barrels)
Total processed inputs (thousands of barrels)
80,456  125,098  44,123  53,614  303,291  
Total processed inputs (thousands of barrels)
92,805 123,924 43,220 54,075 314,024 
Adjusted total processed inputs (thousands of barrels)*
Adjusted total processed inputs (thousands of barrels)*
80,456  125,098  80,358  53,614  339,526  
Adjusted total processed inputs (thousands of barrels)*
92,805 123,924 78,900 54,075 349,704 
Loss before income taxes per barrel (dollars per barrel)**
Loss before income taxes per barrel (dollars per barrel)**
$(10.74) (9.66) (7.50) (13.73) (10.35) 
Loss before income taxes per barrel (dollars per barrel)**
$(2.83)(4.17)(7.64)(12.19)(5.63)
Realized refining margins (dollars per barrel)***
Realized refining margins (dollars per barrel)***
1.97  3.64  10.03  4.92  4.96  
Realized refining margins (dollars per barrel)***
4.73 2.67 6.21 3.35 4.12 
* Adjusted total processed inputs include our proportional share of processed inputs of an equity affiliate. * Adjusted total processed inputs include our proportional share of processed inputs of an equity affiliate. * Adjusted total processed inputs include our proportional share of processed inputs of an equity affiliate.
** Loss before income taxes divided by total processed inputs. ** Loss before income taxes divided by total processed inputs. ** 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.*** 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.*** 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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Millions of Dollars, Except as IndicatedMillions of Dollars, Except as Indicated
Realized Refining MarginsRealized Refining MarginsAtlantic Basin/
Europe
Gulf
Coast
Central CorridorWest
Coast
WorldwideRealized Refining MarginsAtlantic Basin/
Europe
Gulf
Coast
Central
Corridor
West
Coast
Worldwide
Six Months Ended June 30, 2019
Income (loss) before income taxes$251  104  597  (167) 785  
Six Months Ended June 30, 2020Six Months Ended June 30, 2020
Loss before income taxesLoss before income taxes$(864)(1,208)(331)(736)(3,139)
Plus:Plus:Plus:
Taxes other than income taxesTaxes other than income taxes26  39  23  45  133  Taxes other than income taxes34 62 31 53 180 
Depreciation, amortization and impairmentsDepreciation, amortization and impairments99  135  67  125  426  Depreciation, amortization and impairments541 816 502 427 2,286 
Selling, general and administrative expensesSelling, general and administrative expenses17    13  44  Selling, general and administrative expenses25 17 13 19 74 
Operating expensesOperating expenses434  706  279  498  1,917  Operating expenses384 769 256 499 1,908 
Equity in (earnings) losses of affiliatesEquity in (earnings) losses of affiliates  (217) —  (209) Equity in (earnings) losses of affiliates(2)130 — 133 
Other segment (income) expense, net10  (4)   11  
Other segment expense, netOther segment expense, net— 
Proportional share of refining gross margins contributed by equity affiliatesProportional share of refining gross margins contributed by equity affiliates36  —  565  —  601  Proportional share of refining gross margins contributed by equity affiliates32 — 205 — 237 
Special items:
Pending claims and settlements—  —  (21) —  (21) 
Realized refining marginsRealized refining margins$879  988  1,303  517  3,687  Realized refining margins$158 455 806 264 1,683 
Total processed inputs (thousands of barrels)
Total processed inputs (thousands of barrels)
92,854  142,620  50,137  63,400  349,011  
Total processed inputs (thousands of barrels)
80,456 125,098 44,123 53,614 303,291 
Adjusted total processed inputs (thousands of barrels)*
Adjusted total processed inputs (thousands of barrels)*
92,854  142,620  90,828  63,400  389,702  
Adjusted total processed inputs (thousands of barrels)*
80,456 125,098 80,358 53,614 339,526 
Income (loss) before income taxes per barrel (dollars per barrel)**
$2.70  0.73  11.91  (2.63) 2.25  
Loss before income taxes per barrel (dollars per barrel)**
Loss before income taxes per barrel (dollars per barrel)**
$(10.74)(9.66)(7.50)(13.73)(10.35)
Realized refining margins (dollars per barrel)***
Realized refining margins (dollars per barrel)***
9.47  6.93  14.33  8.16  9.46  
Realized refining margins (dollars per barrel)***
1.97 3.64 10.03 4.92 4.96 
* Adjusted total processed inputs include our proportional share of processed inputs of an equity affiliate. * Adjusted total processed inputs include our proportional share of processed inputs of an equity affiliate. * 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.
** Loss before income taxes divided by total processed inputs. ** 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.*** 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.*** 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) purchase 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 refineries’ 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
June 30, 2021
Three Months Ended
June 30, 2020
U.S.InternationalU.S.International
Realized Marketing Fuel Margins
Income before income taxes$366 48 179 68 
Plus:
Taxes other than income taxes2 1 
Depreciation and amortization5 19 16 
Selling, general and administrative expenses198 60 151 57 
Equity in earnings of affiliates(15)(31)(11)(28)
Other operating revenues*(110)(10)(71)(4)
Other segment (income) expense, net (1)— 
Marketing margins446 86 253 112 
Less: margin for nonfuel related sales 15 — 13 
Realized marketing fuel margins$446 71 253 99 
Total fuel sales volumes (thousands of barrels)
170,228 24,539 144,517 19,583 
Income before income taxes per barrel (dollars per barrel)
$2.15 1.96 1.243.48 
Realized marketing fuel margins (dollars per barrel)**
2.62 2.89 1.755.07 
* Includes other nonfuel revenues.
  ** 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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Millions of Dollars, Except as Indicated
Three Months Ended
June 30, 2020
Three Months Ended
June 30, 2019
U.S.InternationalU.S.International
Realized Marketing Fuel Margins
Income before income taxes$179  68  203  129  
Plus:
Taxes other than income taxes    
Depreciation and amortization 16   16  
Selling, general and administrative expenses151  57  183  61  
Equity in earnings of affiliates(11) (28) (3) (25) 
Other operating revenues*(71) (4) (103) (9) 
Other segment expense, net—   —   
Marketing margins253  112  286  174  
Less: margin for nonfuel related sales—  13  —  12  
Realized marketing fuel margins$253  99  286  162  
Total fuel sales volumes (thousands of barrels)
144,517  19,583  186,488  26,837  
Income before income taxes per barrel (dollars per barrel)
$1.24  3.48  1.09  4.81  
Realized marketing fuel margins (dollars per barrel)**
1.75  5.07  1.53  6.03  
* Includes other nonfuel revenues.
  ** 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.
Millions of Dollars, Except as Indicated
Six Months Ended
June 30, 2020
Six Months Ended
June 30, 2019
U.S.InternationalU.S.International
Realized Marketing Fuel Margins
Income before income taxes$478  239  301  187  
Plus:
Taxes other than income taxes    
Depreciation and amortization 33   32  
Selling, general and administrative expenses278  120  338  123  
Equity in earnings of affiliates(11) (50) (4) (47) 
Other operating revenues*(155) (2) (185) (15) 
Other segment (income) expense, net—   —  (1) 
Marketing margins600  344  460  282  
Less: margin for nonfuel related sales—  23  —  22  
Realized marketing fuel margins$600  321  460  260  
Total fuel sales volumes (thousands of barrels)
311,695  45,562  350,546  52,633  
Income before income taxes per barrel (dollars per barrel)
$1.53  5.25  0.86  3.55  
Realized marketing fuel margins (dollars per barrel)**
1.92  7.04  1.31  4.94  
* Includes other nonfuel revenues.
  ** 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.
Millions of Dollars, Except as Indicated
Six Months Ended
June 30, 2021
Six Months Ended
June 30, 2020
U.S.InternationalU.S.International
Realized Marketing Fuel Margins
Income before income taxes$565 96 478 239 
Plus:
Taxes other than income taxes6 3 
Depreciation and amortization8 38 33 
Selling, general and administrative expenses363 120 278 120 
Equity in earnings of affiliates(17)(55)(11)(50)
Other operating revenues*(196)(15)(155)(2)
Other segment (income) expense, net (2)— 
Marketing margins729 185 600 344 
Less: margin for nonfuel related sales 28 — 23 
Realized marketing fuel margins$729 157 600 321 
Total fuel sales volumes (thousands of barrels)
316,022 46,013 311,695 45,562 
Income before income taxes per barrel (dollars per barrel)
$1.79 2.09 1.53 5.25 
Realized marketing fuel margins (dollars per barrel)**
2.31 3.41 1.92 7.04 
* Includes other nonfuel revenues.
  ** 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. 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” and similar expressions, but the absence of such words does not mean a statement is not forward-looking.
We based the 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 in general. We caution you these statements are not guarantees of future performance as they 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 forecast in the forward-looking statements. Any differences could result from a variety of factors, including the following:
General domesticThe continuing effects of the COVID-19 pandemic and international economicits negative impact on commercial activity and political developments including: armed hostilities; expropriation of assets; changes in governmental policies relating to NGL, crude oil, natural gas ordemand for refined petroleum products, pricing, regulation or taxation; actions taken byas well as the membersextent and duration of recovery of economies and demand for our products after the Organization of the Petroleum Exporting Countries (OPEC) affecting the production and pricing of crude oil; and other political, economic or diplomatic developments, including those caused by public health issues, outbreaks of diseases and pandemics, including the COVID-19 pandemic.pandemic subsides.
Fluctuations in NGL, crude oil, refined petroleum product and natural gas prices and refining, marketing and petrochemical margins.
Failure of newChanges in governmental policies relating to NGL, crude oil, natural gas or refined petroleum products pricing, regulation or taxation, including exports.
Actions taken by OPEC and services to achieve market acceptance.other countries impacting supply and demand 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.
Lack of, or disruptions in, adequate and reliable transportation for our NGL, crude oil, natural gas and refined petroleum products.
The level and success of drilling and quality of production volumes around our Midstream assets.
The inability to timely obtain or maintain permits, including those necessary for capital projects.
The inability to comply with government regulations or make capital expenditures required to maintain compliance.
Changes to worldwide government policies relating to renewable fuels and greenhouse gas emissions that adversely affect programs like the renewable fuel standards program, low carbon fuel standards and tax credits for biofuels.
Failure to complete definitive agreements and feasibility studies for, and to complete construction of, announced and future capital projects on time and within budget.
Potential disruption or interruption of our operations due to accidents, weather events (including as a result of climate change), civil unrest, insurrections, political events, terrorism or cyberattacks.
General domestic and international economic and political developments including armed hostilities, expropriation of assets, and other political, economic or diplomatic developments, including those caused by public health issues, outbreaks of diseases and pandemics.
Failure of new products and services to achieve market acceptance.
International monetary conditions and exchange controls.
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Substantial investmentinvestments required, or reduced demand for products, as a result of existing or future environmental rules and regulations.regulations, including reduced consumer demand for refined petroleum products.
Liability resulting from litigation or 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.
Changes in estimates or projections used to assess fair value of intangible assets, goodwill and property and equipment and/or strategic decisions 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.
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The operation, financing and distribution decisions of our joint ventures that we do not control.
Domestic and foreign supplies of crude oil and other feedstocks.
Domestic and foreign supplies of petrochemicals and refined petroleum products, such as gasoline, diesel, aviation fuel and home heating oil.
Governmental policies relating to exports of crude oil and natural gas.
Overcapacity or undercapacity in the midstream, chemicals and refining industries.
Fluctuations in consumer demand for refined petroleum products.
The factors generally described in Item 1A.—Risk Factors in our 20192020 Annual Report on Form 10-K and in Item 1A.—Risk Factors of Part II in this Quarterly Report on Form 10-Q.












































10-K.
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Item 3.   QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Commodity Price Risk
Our commodity price risk and interest rate risk at June 30, 2020,2021, did not differ materially from the risks disclosed under Item 7A of our 20192020 Annual Report on Form 10-K.

Interest Rate Risk
In April 2020, we repaid the $300 million outstanding principal balance of our floating-rate notes due April 2020 and the $200 million outstanding principal balance of our term loan facility due April 2020. Also in April 2020, Phillips 66 Partners repaid the $25 million outstanding principal balance of its tax-exempt bonds due April 2020.

In March 2020, we borrowed $1 billion under our new term loan facility. In April and June 2020, we issued $2 billion in aggregate principal amount of senior notes with varying maturity dates. Because the senior notes have fixed rates, their fair value is sensitive to changes in U.S. interest rates. The following table presents the principal cash flows and associated interest rates of the newly issued debt by expected maturity dates, as of June 30, 2020. The carrying amount of our floating-rate debt approximates its fair value. The fair value of the fixed-rate debt is estimated based on observable market prices.

Millions of Dollars, Except as Indicated
Expected Maturity DateFixed Rate MaturityAverage Interest RateFloating Rate MaturityAverage Interest Rate
Remainder of 2020$—  — %$—  — %
2021—  —  1,000  1.68  
2022—  —  —  —  
2023500  3.70  —  —  
2024—  —  —  —  
Remaining years1,500  2.89  —  —  
Total$2,000  $1,000  
Fair value$2,082  $1,000  





















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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 Securities Exchange Act of 1934, as amended (the Act), is recorded, processed, summarized and reported within the time periods specified in U.S. Securities and Exchange Commission (SEC) 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 June 30, 2020,2021, with the participation of management, our Chairman and Chief Executive Officer and our Executive Vice President, Finance 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, Finance and Chief Financial Officer concluded that our disclosure controls and procedures were operating effectively as of June 30, 2020.2021.

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 June 30, 2020,2021, 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

Although we may, from time to time, be involved in litigation and claims arising out of our operations in the normal course of business, we are not a party to any reportable litigation. Additionally, Item 103 of Regulation S-K promulgated by the U.S. Securities and Exchange Commission (SEC)SEC requires disclosure of certain environmental matters when a governmental authority is a party to the proceedings and such proceedings involve potential monetary sanctions that we reasonably believe will be in excess of $100,000. The following$300,000. There were no such new matters are disclosed in accordance with that requirement. There was one new matter that arose immediately afterduring the second quarter of 2020, as well as material developments that occurred with respect to matters previously reported in our 2019 Annual Report on Form 10-K for the quarterly period ended December 31, 2019. There2021 and there were no material developments that occurred with respect to matters previously reported in our Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2020.reported. We do not currently believe that the eventual outcome of any matters reported, individually or in the aggregate, could have a material adverse effect on our business, financial condition, results of operations or cash flows.

Our U.S. refineries are implementing two separate consent decrees, regarding alleged violations of the Federal Clean Air Act, with the U.S. Environmental Protection Agency (EPA),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 SEC 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.

New Matters
On July 2, 2020,See Note 11—Contingencies and Commitments, in the South Coast Air Quality Management District (SCAQMD) issued a demandNotes to Consolidated Financial Statements, for penalties totaling $2,696,575. The penalty demand proposes to resolve 26 Notices of Violation (NOVs) issued between 2017 and 2020 for alleged violations of air permit and air pollution regulatory requirements at the Los Angeles Refinery. The company is working with SCAQMD to resolve these NOVs.additional information.

Matters Previously Reported
On January 6, 2020, the California State Water Resources Control (Water Board) issued a penalty demand of $558,300 to resolve the Rodeo Refinery’s National Pollutant Discharge Elimination System permit requirement exceedance for total suspended solids that occurred following heavy rains on February 14, 2019. We have reached agreement with the Water Board to resolve this matter with a penalty payment of $142,500 and a monetary contribution of $142,500 for the San Francisco Estuary Institute’s San Francisco Bay Regional Monitoring Program. Final Water Board acceptance of the agreement is subject to a 30-day public comment period that will occur in the third quarter of 2020.

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Item 1A.   RISK FACTORS

Except as provided below, thereThere were no material changes from the risk factors disclosed in Item 1A of our 20192020 Annual Report on Form 10-K.

The outbreak of Coronavirus Disease 2019 (COVID-19) has materially adversely affected, and may continue to materially adversely affect, general economic, financial and business conditions, and could materially and adversely affect our business, financial condition, results of operations and cash flows and those of our customers, suppliers and other counterparties.

The outbreak of COVID-19 continues to negatively impact worldwide economic and commercial activity and financial markets, and uncertainty over economic and business recovery caused by COVID-19 has increased concerns over a prolonged economic slowdown and recession. Responses of governmental authorities, companies and individuals to prevent the spread of COVID-19, including travel restrictions, business and school closures, and stay at home orders, have significantly reduced global economic activity.  These actions have resulted in substantial decreases in the demand for many refined petroleum products we manufacture and sell, particularly gasoline and jet fuel.  Additionally, disputes over production levels resulted in an oversupply of crude oil, further exacerbating the decline in crude oil prices and lower petroleum product prices. Refinery utilization rates and operating margins in our Refining business have already been negatively impacted by these developments. Any prolonged period of economic slowdown or recession, as well as depressed oil prices, may also have a material adverse impact on the financial results of our Midstream, Chemicals, and Marketing and Specialties businesses.  These events also could result in an increased risk that our customers and other counterparties may be unable to fulfill their obligations in a timely manner, or at all, which could negatively affect our financial condition and cash flows. The extent to which COVID-19 will continue to negatively impact our business and operations will depend on how quickly and to what extent economic conditions improve and normal business and operating conditions resume.

Due to declines in the market prices of products held in inventories, certain of our equity affiliates recorded lower-of-cost-or-market inventory charges during the first half of 2020.  Depending on future movements of market prices for products held in inventories, we could be required to make future inventory valuation adjustments, which could affect our financial results.

Any of the foregoing events or conditions, or other consequences of COVID-19, could significantly adversely affect our business and financial condition and the business and financial condition of our customers and other counterparties.  Moreover, many risk factors set forth in our Annual Report on Form 10-K for the year ended December 31, 2019, should be interpreted as heightened risks as a result of the impact of the COVID-19 pandemic.





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Item 2.   UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Issuer Purchases of Equity Securities
In March 2020, we announced that we had temporarily suspended our share repurchases. As of June 30, 2021, we had $2,514 million remaining on our existing share repurchase authorization, which has no expiration date. 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.

Millions of Dollars
PeriodTotal Number of Shares Purchased*Average Price Paid per ShareTotal 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
April 1-30, 2020$— $2,514 
May 1-31, 2020— 2,514 
June 1-30, 2020— 2,514 
Total$— 
  * Includes repurchase of shares of common stock from company employees in connection with the company’s broad-based employee incentive plans, when applicable.
** As of June 30, 2020, our Board of Directors has authorized repurchases of our outstanding common stock under our share repurchase programs totaling $15 billion. The authorizations do not have expiration dates. The share repurchases are expected to be funded primarily through available cash. The shares under these authorizations are repurchased from time to time in the open market at our discretion, subject to market conditions and other factors, and in accordance with applicable regulatory requirements. We are not obligated to acquire any particular amount of common stock and may commence, suspend or discontinue purchases at any time or from time to time without prior notice. Shares of stock repurchased are held as treasury shares. Effective March 18, 2020, share repurchases under our share purchase programs were temporarily suspended.
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Item 6. EXHIBITS
 
Incorporate by Reference
Exhibit
Number
Exhibit DescriptionFormExhibit NumberFiling DateSEC File No.
As permitted by Item 601(b)(4)(iii)(A) of Regulation S-K, the company has not filed with this Quarterly Report on Form 10-Q certain instruments defining the rights of holders of long-term debt of the company and its subsidiaries because the total amount of securities authorized thereunder does not exceed 10% of the total assets of the company and its subsidiaries on a consolidated basis. The company agrees to furnish a copy of such agreements to the Commission upon request.
8-K10.104/07/2020001-35349
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.
Exhibit
Number
Exhibit Description
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.
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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/ Chukwuemeka A. Oyolu
Chukwuemeka A. Oyolu
Vice President and Controller
(Chief Accounting and Duly Authorized Officer)

Date: July 31, 2020August 3, 2021
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