Cover Page
Cover Page - shares | 3 Months Ended | |
Mar. 31, 2021 | Apr. 30, 2021 | |
Cover [Abstract] | ||
Document Type | 10-Q | |
Document Quarterly Report | true | |
Document Period End Date | Mar. 31, 2021 | |
Document Transition Report | false | |
Entity File Number | 1-36132 | |
Entity Registrant Name | PLAINS GP HOLDINGS LP | |
Entity Incorporation, State or Country Code | DE | |
Entity Tax Identification Number | 90-1005472 | |
Entity Address, Address Line One | 333 Clay Street | |
Entity Address, Address Line Two | Suite 1600 | |
Entity Address, City or Town | Houston | |
Entity Address, State or Province | TX | |
Entity Address, Postal Zip Code | 77002 | |
City Area Code | 713 | |
Local Phone Number | 646-4100 | |
Title of 12(b) Security | Class A Shares | |
Trading Symbol | PAGP | |
Security Exchange Name | NASDAQ | |
Entity Current Reporting Status | Yes | |
Entity Interactive Data Current | Yes | |
Entity Filer Category | Large Accelerated Filer | |
Small Business Entity | false | |
Emerging Growth Company | false | |
Entity Shell Company | false | |
Entity Common Stock, Shares Outstanding (shares) | 194,098,315 | |
Entity Central Index Key | 0001581990 | |
Amendment Flag | false | |
Current Fiscal Year End Date | --12-31 | |
Document Fiscal Year Focus | 2021 | |
Document Fiscal Period Focus | Q1 |
CONDENSED CONSOLIDATED BALANCE
CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions | Mar. 31, 2021 | Dec. 31, 2020 |
CURRENT ASSETS | ||
Cash and cash equivalents | $ 32 | $ 25 |
Restricted cash | 26 | 38 |
Trade accounts receivable and other receivables, net | 3,401 | 2,553 |
Inventory | 484 | 647 |
Other current assets | 483 | 405 |
Total current assets | 4,426 | 3,668 |
PROPERTY AND EQUIPMENT | 18,751 | 18,620 |
Accumulated depreciation | (4,159) | (4,000) |
Property and equipment, net | 14,592 | 14,620 |
OTHER ASSETS | ||
Investments in unconsolidated entities | 3,777 | 3,764 |
Deferred tax asset | 1,408 | 1,444 |
Linefill and base gas | 983 | 982 |
Long-term operating lease right-of-use assets, net | 361 | 378 |
Long-term inventory | 178 | 130 |
Other long-term assets, net | 1,022 | 965 |
Total assets | 26,747 | 25,951 |
CURRENT LIABILITIES | ||
Trade accounts payable | 3,399 | 2,425 |
Short-term debt | 254 | 831 |
Other current liabilities | 1,026 | 999 |
Total current liabilities | 4,679 | 4,255 |
LONG-TERM LIABILITIES | ||
Senior notes, net | 9,073 | 9,071 |
Other long-term debt, net | 265 | 311 |
Long-term operating lease liabilities | 303 | 317 |
Other long-term liabilities and deferred credits | 928 | 807 |
Total long-term liabilities | 10,569 | 10,506 |
COMMITMENTS AND CONTINGENCIES (NOTE 10) | ||
PARTNERS’ CAPITAL | ||
Noncontrolling interests | 9,976 | 9,726 |
Total partners’ capital | 11,499 | 11,190 |
Total liabilities and partners’ capital | 26,747 | 25,951 |
Class A Shares | ||
PARTNERS’ CAPITAL | ||
Class A shareholders (194,098,315 and 194,051,436 shares outstanding, respectively) | $ 1,523 | $ 1,464 |
CONDENSED CONSOLIDATED BALANC_2
CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares | Mar. 31, 2021 | Dec. 31, 2020 | Mar. 31, 2020 | Dec. 31, 2019 |
Class A Shares | ||||
Shares outstanding | ||||
Shares outstanding (shares) | 194,098,315 | 194,051,436 | 184,240,079 | 182,138,592 |
CONDENSED CONSOLIDATED STATEMEN
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Millions, $ in Millions | 3 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | |
REVENUES | ||
Total revenues | $ 8,383 | $ 8,269 |
COSTS AND EXPENSES | ||
Purchases and related costs | 7,392 | 7,367 |
Field operating costs | 219 | 304 |
General and administrative expenses | 68 | 70 |
Depreciation and amortization | 178 | 169 |
(Gains)/losses on asset sales and asset impairments, net | 2 | 619 |
Goodwill impairment losses | 0 | 2,515 |
Total costs and expenses | 7,859 | 11,044 |
OPERATING INCOME/(LOSS) | 524 | (2,775) |
OTHER INCOME/(EXPENSE) | ||
Equity earnings in unconsolidated entities | 88 | 110 |
Gain on/(impairment of) investments in unconsolidated entities, net | 0 | (22) |
Interest expense (net of capitalized interest of $5 and $6, respectively) | (107) | (108) |
Other expense, net | (60) | (31) |
INCOME/(LOSS) BEFORE TAX | 445 | (2,826) |
Current income tax expense | (1) | (6) |
Deferred income tax (expense)/benefit | (52) | 140 |
NET INCOME/(LOSS) | 392 | (2,692) |
Net (income)/loss attributable to noncontrolling interests | (322) | 2,111 |
NET INCOME/(LOSS) ATTRIBUTABLE TO PAGP | $ 70 | $ (581) |
Class A Shares | ||
OTHER INCOME/(EXPENSE) | ||
BASIC AND DILUTED NET INCOME/(LOSS) PER CLASS A SHARE (in dollars per share) | $ 0.36 | $ (3.18) |
BASIC AND DILUTED WEIGHTED AVERAGE CLASS A SHARES OUTSTANDING (IN SHARES) | 194 | 183 |
Supply and Logistics | ||
REVENUES | ||
Total revenues | $ 8,083 | $ 7,907 |
Transportation | ||
REVENUES | ||
Total revenues | 137 | 187 |
OTHER INCOME/(EXPENSE) | ||
Equity earnings in unconsolidated entities | 86 | 108 |
Facilities | ||
REVENUES | ||
Total revenues | 163 | 175 |
OTHER INCOME/(EXPENSE) | ||
Equity earnings in unconsolidated entities | $ 2 | $ 2 |
CONDENSED CONSOLIDATED STATEM_2
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Parenthetical) - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | |
Income Statement [Abstract] | ||
Interest expense, capitalized interest | $ 5 | $ 6 |
CONDENSED CONSOLIDATED STATEM_3
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME/(LOSS) - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | |
Statement of Comprehensive Income [Abstract] | ||
Net income/(loss) | $ 392 | $ (2,692) |
Other comprehensive income/(loss) | 108 | (327) |
Comprehensive income/(loss) | 500 | (3,019) |
Comprehensive (income)/loss attributable to noncontrolling interests | (401) | 2,356 |
Comprehensive income/(loss) attributable to PAGP | $ 99 | $ (663) |
CONDENSED CONSOLIDATED STATEM_4
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | |
Changes in Accumulated Other Comprehensive Income/(Loss) | ||
Beginning balance | $ 11,190 | $ 14,485 |
Total period activity | 108 | (327) |
Ending balance | 11,499 | 11,186 |
Derivative Instruments | ||
Changes in Accumulated Other Comprehensive Income/(Loss) | ||
Beginning balance | (258) | (259) |
Reclassification adjustments | 3 | 2 |
Unrealized gain (loss) on hedges | 68 | (79) |
Total period activity | 71 | (77) |
Ending balance | (187) | (336) |
Translation Adjustments | ||
Changes in Accumulated Other Comprehensive Income/(Loss) | ||
Beginning balance | (657) | (674) |
Currency translation adjustments | 37 | (251) |
Total period activity | 37 | (251) |
Ending balance | (620) | (925) |
Other | ||
Changes in Accumulated Other Comprehensive Income/(Loss) | ||
Beginning balance | (3) | 0 |
Other | 1 | |
Total period activity | 0 | 1 |
Ending balance | (3) | 1 |
Total | ||
Changes in Accumulated Other Comprehensive Income/(Loss) | ||
Beginning balance | (918) | (933) |
Reclassification adjustments | 3 | 2 |
Unrealized gain (loss) on hedges | 68 | (79) |
Currency translation adjustments | 37 | (251) |
Other | 1 | |
Total period activity | 108 | (327) |
Ending balance | $ (810) | $ (1,260) |
CONDENSED CONSOLIDATED STATEM_5
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | |
CASH FLOWS FROM OPERATING ACTIVITIES | ||
Net income/(loss) | $ 392 | $ (2,692) |
Reconciliation of net income/(loss) to net cash provided by operating activities: | ||
Depreciation and amortization | 178 | 169 |
(Gains)/losses on asset sales and asset impairments, net | 2 | 619 |
Goodwill impairment losses | 0 | 2,515 |
Inventory valuation adjustments | 0 | 232 |
Deferred income tax expense/(benefit) | 52 | (140) |
(Gain)/loss on foreign currency revaluation | (8) | 46 |
Change in fair value of Preferred Distribution Rate Reset Option (Note 8) | 67 | (26) |
Equity earnings in unconsolidated entities | (88) | (110) |
Distributions on earnings from unconsolidated entities | 110 | 125 |
(Gain on)/impairment of investments in unconsolidated entities, net | 0 | 22 |
Other | 14 | 1 |
Changes in assets and liabilities, net of acquisitions | 70 | 128 |
Net cash provided by operating activities | 789 | 889 |
CASH FLOWS FROM INVESTING ACTIVITIES | ||
Cash paid in connection with acquisitions, net of cash acquired | 0 | (308) |
Investments in unconsolidated entities | (35) | (147) |
Additions to property, equipment and other | (97) | (245) |
Proceeds from sales of assets | 21 | 104 |
Other investing activities | 3 | (14) |
Net cash used in investing activities | (108) | (610) |
CASH FLOWS FROM FINANCING ACTIVITIES | ||
Net repayments under PAA commercial paper program (Note 6) | (410) | (93) |
Net borrowings/(repayments) under PAA senior secured hedged inventory facility (Note 6) | (166) | 89 |
Distributions paid to Class A shareholders (Note 7) | (35) | (66) |
Distributions paid to noncontrolling interests (Note 7) | (138) | (233) |
Other financing activities | 63 | 112 |
Net cash used in financing activities | (686) | (191) |
Effect of translation adjustment | 0 | (10) |
Net increase/(decrease) in cash and cash equivalents and restricted cash | (5) | 78 |
Cash and cash equivalents and restricted cash, beginning of period | 63 | 84 |
Cash and cash equivalents and restricted cash, end of period | 58 | 162 |
Cash paid for: | ||
Interest, net of amounts capitalized | 65 | 65 |
Income taxes, net of amounts refunded | $ 24 | $ 51 |
CONDENSED CONSOLIDATED STATEM_6
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL - USD ($) $ in Millions | Total | Noncontrolling Interests | Limited PartnersClass A Shares |
Beginning balance at Dec. 31, 2019 | $ 14,485 | $ 12,330 | $ 2,155 |
Increase (Decrease) in Partners' Capital | |||
Net income/(loss) | (2,692) | (2,111) | (581) |
Distributions (Note 7) | (311) | (245) | (66) |
Deferred tax asset | 20 | 0 | 20 |
Other comprehensive income/(loss) | (327) | (245) | (82) |
Contributions from noncontrolling interests | 8 | 8 | 0 |
Other | 3 | (8) | 11 |
Ending balance at Mar. 31, 2020 | 11,186 | 9,729 | 1,457 |
Beginning balance at Dec. 31, 2020 | 11,190 | 9,726 | 1,464 |
Increase (Decrease) in Partners' Capital | |||
Net income/(loss) | 392 | 322 | 70 |
Distributions (Note 7) | (185) | (150) | (35) |
Deferred tax asset | (7) | 0 | (7) |
Other comprehensive income/(loss) | 108 | 79 | 29 |
Contributions from noncontrolling interests | 1 | 1 | 0 |
Other | 0 | (2) | 2 |
Ending balance at Mar. 31, 2021 | $ 11,499 | $ 9,976 | $ 1,523 |
Organization and Basis of Conso
Organization and Basis of Consolidation and Presentation | 3 Months Ended |
Mar. 31, 2021 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Organization and Basis of Consolidation and Presentation | Organization and Basis of Consolidation and Presentation Organization Plains GP Holdings, L.P. (“PAGP”) is a Delaware limited partnership formed in 2013 that has elected to be taxed as a corporation for United States federal income tax purposes. PAGP does not directly own any operating assets; as of March 31, 2021, its principal sources of cash flow are derived from an indirect investment in Plains All American Pipeline, L.P. (“PAA”), a publicly traded Delaware limited partnership. As used in this Form 10-Q and unless the context indicates otherwise (taking into account the fact that PAGP has no operating activities apart from those conducted by PAA and its subsidiaries), the terms “Partnership,” “we,” “us,” “our,” “ours” and similar terms refer to PAGP and its subsidiaries. As of March 31, 2021, PAGP owned (i) a 100% managing member interest in Plains All American GP LLC (“GP LLC”), an entity that has also elected to be taxed as a corporation for United States federal income tax purposes and (ii) an approximate 79% limited partner interest in Plains AAP, L.P. (“AAP”) through our direct ownership of approximately 193.1 million Class A units of AAP (“AAP units”) and indirect ownership of approximately 1.0 million AAP units through GP LLC. GP LLC is a Delaware limited liability company that also holds the non-economic general partner interest in AAP. AAP is a Delaware limited partnership that, as of March 31, 2021, directly owned a limited partner interest in PAA through its ownership of approximately 245.5 million PAA common units (approximately 31% of PAA’s total outstanding common units and Series A preferred units combined). AAP is the sole member of PAA GP LLC (“PAA GP”), a Delaware limited liability company that directly holds the non-economic general partner interest in PAA. PAA’s business model integrates large-scale supply aggregation capabilities with the ownership and operation of critical midstream infrastructure systems that connect major producing regions to key demand centers and export terminals. As one of the largest midstream service providers in North America, PAA owns an extensive network of pipeline transportation, terminalling, storage and gathering assets in key crude oil and natural gas liquids (“NGL”) producing basins (including the Permian Basin) and transportation corridors and at major market hubs in the United States and Canada. PAA’s assets and the services it provides are primarily focused on crude oil, NGL and natural gas. PAA’s business activities are conducted through three operating segments: Transportation, Facilities and Supply and Logistics. See Note 11 for further discussion of our operating segments. PAA GP Holdings LLC, a Delaware limited liability company, is our general partner. Our general partner manages our operations and activities and is responsible for exercising on our behalf any rights we have as the sole and managing member of GP LLC, including responsibility for conducting the business and managing the operations of AAP and PAA. GP LLC employs our domestic officers and personnel involved in the operation and management of AAP and PAA. PAA’s Canadian officers and personnel are employed by our subsidiary, Plains Midstream Canada ULC. References to the “Plains Entities” include us, our general partner, GP LLC, AAP, PAA GP and PAA and its subsidiaries. Definitions Additional defined terms are used in this Form 10-Q and shall have the meanings indicated below: AOCI = Accumulated other comprehensive income/(loss) ASC = Accounting Standards Codification ASU = Accounting Standards Update Bcf = Billion cubic feet Btu = British thermal unit CAD = Canadian dollar CODM = Chief Operating Decision Maker EBITDA = Earnings before interest, taxes, depreciation and amortization EPA = United States Environmental Protection Agency FASB = Financial Accounting Standards Board GAAP = Generally accepted accounting principles in the United States ICE = Intercontinental Exchange ISDA = International Swaps and Derivatives Association LIBOR = London Interbank Offered Rate LTIP = Long-term incentive plan Mcf = Thousand cubic feet MMbls = Million barrels NGL = Natural gas liquids, including ethane, propane and butane NYMEX = New York Mercantile Exchange SEC = United States Securities and Exchange Commission TWh = Terawatt hour USD = United States dollar WTI = West Texas Intermediate Basis of Consolidation and Presentation The accompanying unaudited condensed consolidated interim financial statements and related notes thereto should be read in conjunction with our 2020 Annual Report on Form 10-K. The accompanying condensed consolidated financial statements include the accounts of PAGP and all of its wholly owned subsidiaries and those entities that it controls. Investments in entities over which we have significant influence but not control are accounted for by the equity method. We apply proportionate consolidation for pipelines and other assets in which we own undivided joint interests. The financial statements have been prepared in accordance with the instructions for interim reporting as set forth by the SEC. All adjustments (consisting only of normal recurring adjustments) that in the opinion of management were necessary for a fair statement of the results for the interim periods have been reflected. All significant intercompany transactions have been eliminated in consolidation, and certain reclassifications have been made to information from previous years to conform to the current presentation. The condensed consolidated balance sheet data as of December 31, 2020 was derived from audited financial statements, but does not include all disclosures required by GAAP. The results of operations for the three months ended March 31, 2021 should not be taken as indicative of results to be expected for the entire year. Management judgment is required to evaluate whether PAGP controls an entity. Key areas of that evaluation include (i) determining whether an entity is a variable interest entity (“VIE”); (ii) determining whether PAGP is the primary beneficiary of a VIE, including evaluating which activities of the VIE most significantly impact its economic performance and the degree of power that PAGP and its related parties have over those activities through variable interests; and (iii) identifying events that require reconsideration of whether an entity is a VIE and continuously evaluating whether PAGP is a VIE’s primary beneficiary. We have determined that our subsidiaries, PAA and AAP, are VIEs and should be consolidated by PAGP because: • The limited partners of PAA and AAP lack (i) substantive “kick-out rights” (i.e., the right to remove the general partner) based on a simple majority or lower vote and (ii) substantive participation rights and thus lack the ability to block actions of the general partner that most significantly impact the economic performance of PAA and AAP, respectively. • AAP is the primary beneficiary of PAA because it has the power to direct the activities that most significantly impact PAA’s performance and the right to receive benefits, and obligation to absorb losses, that could be significant to PAA. • PAGP is the primary beneficiary of AAP because it has the power to direct the activities that most significantly impact AAP’s performance and the right to receive benefits, and obligation to absorb losses, that could be significant to AAP. With the exception of a deferred tax asset of $1.408 billion and $1.444 billion as of March 31, 2021 and December 31, 2020, respectively, substantially all assets and liabilities presented on PAGP’s Condensed Consolidated Balance Sheets are those of PAA. Only the assets of each respective VIE can be used to settle the obligations of that individual VIE, and the creditors of each/either of those VIEs do not have recourse against the general credit of PAGP. PAGP did not provide any financial support to PAA or AAP during the three months ended March 31, 2021 or the year ended December 31, 2020. See Note 17 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for information regarding the Omnibus Agreement entered into by the Plains Entities on November 15, 2016. |
Summary of Significant Accounti
Summary of Significant Accounting Policies | 3 Months Ended |
Mar. 31, 2021 | |
Accounting Policies [Abstract] | |
Summary of Significant Accounting Policies | Summary of Significant Accounting Policies Restricted Cash Restricted cash includes cash held by us that is unavailable for general use and is comprised of amounts advanced to us by certain equity method investees related to the construction of fixed assets where we serve as construction manager. The following table presents a reconciliation of cash and cash equivalents and restricted cash reported on our Condensed Consolidated Balance Sheets that sum to the total of the amounts shown on our Condensed Consolidated Statements of Cash Flows (in millions): March 31, December 31, Cash and cash equivalents $ 32 $ 25 Restricted cash 26 38 Total cash and cash equivalents and restricted cash $ 58 $ 63 Property and Equipment During the first quarter of 2021, we modified the useful lives of certain of our Pipeline and related facilities and Storage, terminal and rail facilities to useful lives of 10 to 50 years from useful lives of 10 to 70 years to reflect current expectations given our future operating and commercial outlook. These depreciable life adjustments will prospectively increase depreciation expense. For the three months ended March 31, 2021, these reductions increased depreciation expense by approximately $18 million, which resulted in a decrease to both basic and diluted net income per Class A share of approximately $0.02 from what it would have been absent the change in useful lives. Recent Accounting Pronouncements Except as discussed below and in our 2020 Annual Report on Form 10-K, there have been no new accounting pronouncements that have become effective or have been issued during the three months ended March 31, 2021 that are of significance or potential significance to us. Accounting Standards Updates Adopted During the Period We adopted the ASU listed below effective January 1, 2021 and our adoption did not have a material impact on our financial position, results of operations or cash flows (see Note 2 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for additional information regarding this ASU): • ASU 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes. |
Revenues and Accounts Receivabl
Revenues and Accounts Receivable | 3 Months Ended |
Mar. 31, 2021 | |
Revenue from Contract with Customer [Abstract] | |
Revenues and Accounts Receivable | Revenues and Accounts Receivable Revenue Recognition We disaggregate our revenues by segment and type of activity. These categories depict how the nature, amount, timing and uncertainty of revenues and cash flows are affected by economic factors. See Note 3 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for additional information regarding our types of revenues and policies for revenue recognition. The following tables present our Supply and Logistics, Transportation and Facilities segment revenues from contracts with customers disaggregated by type of activity (in millions): Three Months Ended 2021 2020 Supply and Logistics segment revenues from contracts with customers Crude oil transactions $ 7,711 $ 7,322 NGL and other transactions 684 428 Total Supply and Logistics segment revenues from contracts with customers $ 8,395 $ 7,750 Three Months Ended 2021 2020 Transportation segment revenues from contracts with customers Tariff activities: Crude oil pipelines $ 397 $ 512 NGL pipelines 27 26 Total tariff activities 424 538 Trucking 22 35 Total Transportation segment revenues from contracts with customers $ 446 $ 573 Three Months Ended 2021 2020 Facilities segment revenues from contracts with customers Crude oil, NGL and other terminalling and storage $ 170 $ 182 NGL and natural gas processing and fractionation 73 109 Rail load / unload 11 14 Total Facilities segment revenues from contracts with customers $ 254 $ 305 Reconciliation to Total Revenues of Reportable Segments. The following disclosures only include information regarding revenues associated with consolidated entities; revenues from entities accounted for by the equity method are not included. The following tables present the reconciliation of our revenues from contracts with customers (as described above for each segment) to segment revenues and total revenues as disclosed in our Condensed Consolidated Statements of Operations (in millions): Three Months Ended March 31, 2021 Transportation Facilities Supply and Total Revenues from contracts with customers $ 446 $ 254 $ 8,395 $ 9,095 Other items in revenues 41 17 (312) (254) Total revenues of reportable segments $ 487 $ 271 $ 8,083 $ 8,841 Intersegment revenues (458) Total revenues $ 8,383 Three Months Ended March 31, 2020 Transportation Facilities Supply and Total Revenues from contracts with customers $ 573 $ 305 $ 7,750 $ 8,628 Other items in revenues 6 8 158 172 Total revenues of reportable segments $ 579 $ 313 $ 7,908 $ 8,800 Intersegment revenues (531) Total revenues $ 8,269 Minimum Volume Commitments. We have certain agreements that require counterparties to transport or throughput a minimum volume over an agreed upon period. The following table presents counterparty deficiencies associated with contracts with customers and buy/sell arrangements that include minimum volume commitments for which we had remaining performance obligations and the customers still had the ability to meet their obligations (in millions): Counterparty Deficiencies Financial Statement Classification March 31, December 31, Billed and collected Liability $ 47 $ 73 Unbilled (1) N/A 24 4 Total $ 71 $ 77 (1) Amounts were related to deficiencies for which the counterparties had not met their contractual minimum commitments and are not reflected in our Condensed Consolidated Financial Statements as we had not yet billed or collected such amounts. Contract Balances . Our contract balances consist of amounts received associated with services or sales for which we have not yet completed the related performance obligation. The following table presents the change in the liability balance associated with contracts with customers (in millions): Contract Liabilities Balance at December 31, 2020 $ 501 Amounts recognized as revenue (1) (380) Additions (2) 373 Balance at March 31, 2021 $ 494 (1) Includes approximately $361 million associated with crude oil sales agreements that were entered into in the fourth quarter of 2020 in conjunction with storage arrangements and future inventory exchanges. (2) Includes approximately $346 million associated with crude oil sales agreements that were entered into in the first quarter of 2021 in conjunction with storage arrangements and future inventory exchanges. Such amount is expected to be recognized as revenue in the second quarter of 2021. Remaining Performance Obligations . The information below includes the amount of consideration allocated to partially and wholly unsatisfied remaining performance obligations under contracts that exist as of the end of the periods and the timing of revenue recognition of those remaining performance obligations. Certain contracts meet the requirements for the presentation as remaining performance obligations. These arrangements include a fixed minimum level of service, typically a set volume of service, and do not contain any variability other than expected timing within a limited range. The following table presents the amount of consideration associated with remaining performance obligations for the population of contracts with external customers meeting the presentation requirements as of March 31, 2021 (in millions): Remainder of 2021 2022 2023 2024 2025 2026 and Thereafter Pipeline revenues supported by minimum volume commitments and capacity agreements (1) $ 135 $ 171 $ 171 $ 146 $ 126 $ 456 Storage, terminalling and throughput agreement revenues 275 302 220 179 116 332 Total $ 410 $ 473 $ 391 $ 325 $ 242 $ 788 (1) Calculated as volumes committed under contracts multiplied by the current applicable tariff rate. The presentation above does not include (i) expected revenues from legacy shippers not underpinned by minimum volume commitments, including pipelines where there are no or limited alternative pipeline transportation options, (ii) intersegment revenues and (iii) the amount of consideration associated with certain income generating contracts, which include a fixed minimum level of service, that are either not within the scope of ASC 606 or do not meet the requirements for presentation as remaining performance obligations. The following are examples of contracts that are not included in the table above because they are not within the scope of ASC 606 or do not meet the requirements for presentation: • Minimum volume commitments on certain of our joint venture pipeline systems; • Acreage dedications; • Supply and Logistics buy/sell arrangements with future committed volumes; • All other Supply and Logistics contracts, due to the election of practical expedients related to variable consideration and short-term contracts; • Transportation and Facilities contracts that are short-term; • Contracts within the scope of ASC 842, Leases ; and • Contracts within the scope of ASC 815, Derivatives and Hedging . Trade Accounts Receivable and Other Receivables, Net Our accounts receivable are primarily from purchasers and shippers of crude oil and, to a lesser extent, purchasers of NGL. These purchasers include, but are not limited to, refiners, producers, marketing and trading companies and financial institutions. The majority of our accounts receivable relate to our crude oil supply and logistics activities that can generally be described as high volume and low margin activities, in many cases involving exchanges of crude oil volumes. During 2020, macroeconomic and geopolitical conditions including the collapse of oil prices driven by both the decrease in demand caused by the COVID-19 pandemic and excess supply has caused liquidity issues impacting many energy companies, which in turn has increased the potential credit risks associated with certain counterparties with which we do business. To mitigate credit risk related to our accounts receivable, we utilize a rigorous credit review process. We closely monitor market conditions and perform credit reviews of each customer to make a determination with respect to the amount, if any, of open credit to be extended to any given customer and the form and amount of financial performance assurances we require. Such financial assurances are commonly provided to us in the form of advance cash payments, standby letters of credit, credit insurance or parental guarantees. Additionally, in an effort to mitigate credit risk, a significant portion of our transactions with counterparties are settled on a net-cash basis. For a majority of these net-cash arrangements, we also enter into netting agreements (contractual agreements that allow us to offset receivables and payables with those counterparties against each other on our balance sheet). Accounts receivable from the sale of crude oil are generally settled with counterparties on the industry settlement date, which is typically in the month following the month in which the title transfers. Otherwise, we generally invoice customers within 30 days of when the products or services were provided and generally require payment within 30 days of the invoice date. We review all outstanding accounts receivable balances on a monthly basis and record our receivables net of expected credit losses. We do not write-off accounts receivable balances until we have exhausted substantially all collection efforts. At March 31, 2021 and December 31, 2020, substantially all of our trade accounts receivable were less than 30 days past their invoice date. Our expected credit losses are immaterial. Although we consider our credit procedures to be adequate to mitigate any significant credit losses, the actual amount of current and future credit losses could vary significantly from estimated amounts. The following is a reconciliation of trade accounts receivable from revenues from contracts with customers to total Trade accounts receivable and other receivables, net as presented on our Condensed Consolidated Balance Sheets (in millions): March 31, December 31, 2020 Trade accounts receivable arising from revenues from contracts with customers $ 3,140 $ 2,317 Other trade accounts receivables and other receivables (1) 3,582 2,818 Impact due to contractual rights of offset with counterparties (3,321) (2,582) Trade accounts receivable and other receivables, net $ 3,401 $ 2,553 (1) The balance is comprised primarily of accounts receivable associated with buy/sell arrangements that are not within the scope of ASC 606. |
Net Income_(Loss) Per Class A S
Net Income/(Loss) Per Class A Share | 3 Months Ended |
Mar. 31, 2021 | |
Earnings Per Share [Abstract] | |
Net Income/(Loss) Per Class A Share | Net Income/(Loss) Per Class A Share Basic net income/(loss) per Class A share is determined by dividing net income/(loss) attributable to PAGP by the weighted average number of Class A shares outstanding during the period. Our Class B and Class C shares do not share in the earnings of the Partnership; accordingly, basic and diluted net income per Class B and Class C share has not been presented. Diluted net income/(loss) per Class A share is determined by dividing net income/(loss) attributable to PAGP by the diluted weighted average number of Class A shares outstanding during the period. For purposes of calculating diluted net income per Class A share, both the net income/(loss) attributable to PAGP and the diluted weighted average number of Class A shares outstanding consider the impact of possible future exchanges of (i) AAP units and the associated Class B shares into our Class A shares and (ii) Class B units of AAP (referred to herein as “AAP Management Units”) into our Class A shares. In addition, the calculation of the diluted weighted average number of Class A shares outstanding considers the effect of potentially dilutive awards under the Plains GP Holdings, L.P. Long-Term Incentive Plan (the “PAGP LTIP”). All AAP Management Units that have satisfied the applicable performance conditions are considered potentially dilutive. Exchanges of potentially dilutive AAP units and AAP Management Units are assumed to have occurred at the beginning of the period and the incremental income attributable to PAGP resulting from the assumed exchanges is representative of the incremental income that would have been attributable to PAGP if the assumed exchanges occurred on that date. See Note 12 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for information regarding exchanges of AAP units and AAP Management Units. PAGP LTIP awards that are deemed to be dilutive are reduced by a hypothetical share repurchase based on the remaining unamortized fair value, as prescribed by the treasury stock method in guidance issued by the FASB. See Note 18 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for information regarding PAGP LTIP awards. On a weighted-average basis, for the three months ended March 31, 2021 and 2020, the possible exchange of 51 million and 63 million AAP units, respectively, would not have had a dilutive effect on basic net income/(loss) per Class A share. For both the three months ended March 31, 2021 and 2020, the possible exchange of 1 million AAP Management Units would not have had a dilutive effect on basic net income/(loss) per Class A share on a weighted-average basis. For the three months ended March 31, 2021, our PAGP LTIP awards were dilutive; however, there were less than 0.1 million dilutive LTIP awards, which did not change the presentation of diluted weighted average Class A shares outstanding or diluted net income/(loss) per Class A share. For the three months ended March 31, 2020, our PAGP LTIP awards were antidilutive. The following table sets forth the computation of basic and diluted net income/(loss) per Class A share (in millions, except per share data): Three Months Ended 2021 2020 Basic and Diluted Net Income/(Loss) per Class A Share Net income/(loss) attributable to PAGP $ 70 $ (581) Basic and diluted weighted average Class A shares outstanding 194 183 Basic and diluted net income/(loss) per Class A share $ 0.36 $ (3.18) |
Inventory, Linefill and Base Ga
Inventory, Linefill and Base Gas and Long-term Inventory | 3 Months Ended |
Mar. 31, 2021 | |
Inventory, Linefill and Base Gas and Long-term Inventory | |
Inventory, Linefill and Base Gas and Long-term Inventory | Inventory, Linefill and Base Gas and Long-term Inventory Inventory, linefill and base gas and long-term inventory consisted of the following (barrels and natural gas volumes in thousands and carrying value in millions): March 31, 2021 December 31, 2020 Volumes Unit of Carrying Price/ Unit (1) Volumes Unit of Carrying Price/ Unit (1) Inventory Crude oil 8,896 barrels $ 373 $ 41.93 13,450 barrels $ 441 $ 32.79 NGL 4,872 barrels 105 $ 21.55 12,302 barrels 199 $ 16.18 Other N/A 6 N/A N/A 7 N/A Inventory subtotal 484 647 Linefill and base gas Crude oil 14,653 barrels 828 $ 56.51 14,669 barrels 828 $ 56.45 NGL 1,650 barrels 45 $ 27.27 1,640 barrels 44 $ 26.83 Natural gas 25,576 Mcf 110 $ 4.30 25,576 Mcf 110 $ 4.30 Linefill and base gas subtotal 983 982 Long-term inventory Crude oil 2,669 barrels 154 $ 57.70 2,499 barrels 111 $ 44.42 NGL 1,105 barrels 24 $ 21.72 1,185 barrels 19 $ 16.03 Long-term inventory subtotal 178 130 Total $ 1,645 $ 1,759 (1) Price per unit of measure is comprised of a weighted average associated with various grades, qualities and locations. Accordingly, these prices may not coincide with any published benchmarks for such products. |
Debt
Debt | 3 Months Ended |
Mar. 31, 2021 | |
Debt Disclosure [Abstract] | |
Debt | Debt Debt consisted of the following (in millions): March 31, December 31, SHORT-TERM DEBT PAA commercial paper notes, bearing a weighted-average interest rate of 0.6% and 0.7%, respectively (1) $ 137 $ 547 PAA senior secured hedged inventory facility, bearing a weighted-average interest rate of 1.2% (1) — 167 Other 117 117 Total short-term debt 254 831 LONG-TERM DEBT PAA senior notes, net of unamortized discounts and debt issuance costs of $60 and $62, respectively 9,073 9,071 PAA GO Zone term loans, net of debt issuance costs of $1 and $1, respectively, bearing a weighted-average interest rate of 1.3% and 1.3%, respectively 199 199 Other 66 112 Total long-term debt 9,338 9,382 Total debt (2) $ 9,592 $ 10,213 (1) We classified these commercial paper notes as short-term as of March 31, 2021 and December 31, 2020, respectively, and these credit facility borrowings as short-term as of December 31, 2020, as these notes and borrowings were primarily designated as working capital borrowings, were required to be repaid within one year and were primarily for hedged NGL and crude oil inventory and NYMEX and ICE margin deposits. (2) PAA’s fixed-rate senior notes had a face value of approximately $9.1 billion at both March 31, 2021 and December 31, 2020. We estimated the aggregate fair value of these notes as of March 31, 2021 and December 31, 2020 to be approximately $9.5 billion and $9.9 billion, respectively. PAA’s fixed-rate senior notes are traded among institutions, and these trades are routinely published by a reporting service. Our determination of fair value is based on reported trading activity near the end of the reporting period. We estimate that the carrying value of outstanding borrowings under PAA’s credit facilities, commercial paper program and GO Zone term loans approximates fair value as interest rates reflect current market rates. The fair value estimates for PAA’s senior notes, credit facilities, commercial paper program and GO Zone term loans are based upon observable market data and are classified in Level 2 of the fair value hierarchy. Borrowings and Repayments Total borrowings under the PAA credit facilities and commercial paper program for the three months ended March 31, 2021 and 2020 were approximately $14.2 billion and $9.6 billion, respectively. Total repayments under the PAA credit facilities and commercial paper program were approximately $14.8 billion and $9.6 billion for the three months ended March 31, 2021 and 2020, respectively. The variance in total gross borrowings and repayments is impacted by various business and financial factors including, but not limited to, the timing, average term and method of general partnership borrowing activities. Letters of Credit In connection with our supply and logistics activities, we provide certain suppliers with irrevocable standby letters of credit to secure our obligation for the purchase and transportation of crude oil, NGL and natural gas. Additionally, we issue letters of credit to support insurance programs, derivative transactions, including hedging-related margin obligations, and construction activities. At March 31, 2021 and December 31, 2020, we had outstanding letters of credit of $130 million and $129 million, respectively. |
Partners' Capital and Distribut
Partners' Capital and Distributions | 3 Months Ended |
Mar. 31, 2021 | |
Partners' Capital Notes [Abstract] | |
Partners' Capital and Distributions | Partners’ Capital and Distributions Shares Outstanding The following tables present the activity for our Class A shares, Class B shares and Class C shares: Class A Shares Class B Shares Class C Shares Outstanding at December 31, 2020 194,051,436 50,640,192 547,717,762 Conversion of AAP Management Units (1) — 414,608 — Exchange Right exercises (1) 46,879 (46,879) — Redemption Right exercises (1) — (229,931) 229,931 Repurchase of common units by a subsidiary under Common Equity Repurchase Program (2) — — (350,000) Other — — 25,431 Outstanding at March 31, 2021 194,098,315 50,777,990 547,623,124 Class A Shares Class B Shares Class C Shares Outstanding at December 31, 2019 182,138,592 65,785,702 549,538,139 Conversion of AAP Management Units (1) — 559,768 — Exchange Right exercises (1) 2,101,487 (2,101,487) — Redemption Right exercises (1) — (1,206,599) 1,206,599 Other — — 24,431 Outstanding at March 31, 2020 184,240,079 63,037,384 550,769,169 (1) See Note 12 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for information regarding conversions of AAP Management Units, Exchange Rights and Redemption Rights. (2) Trades for these units were executed in late December 2020, but settled in early January 2021. Distributions The following table details distributions to our Class A shareholders paid during or pertaining to the first three months of 2021 (in millions, except per share data): Distribution Payment Date Distributions to Distributions per May 14, 2021 (1) $ 35 $ 0.18 February 12, 2021 $ 35 $ 0.18 (1) Payable to shareholders of record at the close of business on April 30, 2021 for the period from January 1, 2021 through March 31, 2021. Consolidated Subsidiaries Noncontrolling Interests in Subsidiaries As of March 31, 2021, noncontrolling interests in our subsidiaries consisted of (i) limited partner interests in PAA including a 69% interest in PAA’s common units and PAA’s Series A preferred units combined and 100% of PAA’s Series B preferred units, (ii) an approximate 21% limited partner interest in AAP and (iii) a 33% interest in Red River Pipeline Company LLC (“Red River LLC”). During the three months ended March 31, 2021, we paid distributions of $6 million to noncontrolling interests in Red River Pipeline Company LLC. Subsidiary Distributions PAA Series A Preferred Unit Distributions . The following table details distributions to PAA’s Series A preferred unitholders paid during or pertaining to the first three months of 2021 (in millions, except per unit data): Series A Preferred Unitholders Distribution Payment Date Cash Distribution Distribution per Unit May 14, 2021 (1) $ 37 $ 0.525 February 12, 2021 $ 37 $ 0.525 (1) Payable to unitholders of record at the close of business on April 30, 2021 for the period from January 1, 2021 through March 31, 2021. At March 31, 2021, such amount was accrued as distributions payable in “Other current liabilities” on our Condensed Consolidated Balance Sheet. PAA Series B Preferred Unit Distributions . Distributions on PAA’s Series B preferred units are payable semi-annually in arrears on the 15th day of May and November. The following table details distributions to be paid to PAA’s Series B preferred unitholders (in millions, except per unit data): Series B Preferred Unitholders Distribution Payment Date Cash Distribution Distribution per Unit May 17, 2021 (1) $ 24.5 $ 30.625 (1) Payable to unitholders of record at the close of business on May 3, 2021 for the period from November 15, 2020 through May 14, 2021. At March 31, 2021, approximately $18 million of accrued distributions payable to PAA’s Series B preferred unitholders was included in “Other current liabilities” on our Condensed Consolidated Balance Sheet. PAA Common Unit Distributions. The following table details distributions to PAA’s common unitholders paid during or pertaining to the first three months of 2021 (in millions, except per unit data): Distributions Cash Distribution Common Unitholders Total Cash Distribution Distribution Payment Date Public AAP May 14, 2021 (1) $ 86 $ 44 $ 130 $ 0.18 February 12, 2021 $ 86 $ 44 $ 130 $ 0.18 (1) Payable to unitholders of record at the close of business on April 30, 2021 for the period from January 1, 2021 through March 31, 2021. AAP Distributions. The following table details the distributions to AAP’s partners paid during or pertaining to the first three months of 2021 from distributions received from PAA (in millions): Distributions to AAP ’ s Partners Distribution Payment Date Noncontrolling Interests PAGP Total Cash Distribution May 14, 2021 (1) $ 9 $ 35 $ 44 February 12, 2021 $ 9 $ 35 $ 44 (1) Payable to unitholders of record at the close of business on April 30, 2021 for the period from January 1, 2021 through March 31, 2021. |
Derivatives and Risk Management
Derivatives and Risk Management Activities | 3 Months Ended |
Mar. 31, 2021 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Derivatives and Risk Management Activities | Derivatives and Risk Management Activities We identify the risks that underlie our core business activities and use risk management strategies to mitigate those risks when we determine that there is value in doing so. We use various derivative instruments to optimize our profits while managing our exposure to (i) hydrocarbon commodity (referred to herein as “commodity”) price risk, (ii) interest rate risk and (iii) currency exchange rate risk. Our commodity price risk management policies and procedures are designed to help ensure that our hedging activities address our risks by monitoring our derivative positions, as well as physical volumes, grades, locations, delivery schedules and storage capacity. Our interest rate and currency exchange rate risk management policies and procedures are designed to monitor our derivative positions and ensure that those positions are consistent with our objectives and approved strategies. Our policy is to use derivative instruments for risk management purposes and not for the purpose of speculating on changes in commodity prices, interest rates or currency exchange rates. When we apply hedge accounting, our policy is to formally document all relationships between hedging instruments and hedged items, as well as our risk management objectives for undertaking the hedge. This process includes specific identification of the hedging instrument and the hedged transaction, the nature of the risk being hedged and how the hedging instrument’s effectiveness will be assessed. At the inception of the hedging relationship, we assess whether the derivatives employed are highly effective in offsetting changes in cash flows of anticipated hedged transactions. Throughout the hedging relationship, retrospective and prospective hedge effectiveness is assessed on a qualitative basis. We record all open derivatives on the balance sheet as either assets or liabilities measured at fair value. Changes in the fair value of derivatives are recognized currently in earnings unless specific hedge accounting criteria are met. For derivatives designated as cash flow hedges, changes in fair value are deferred in AOCI and recognized in earnings in the periods during which the underlying hedged transactions are recognized in earnings. Derivatives that are not designated in a hedging relationship for accounting purposes are recognized in earnings each period. Cash settlements associated with our derivative activities are classified within the same category as the related hedged item in our Condensed Consolidated Statements of Cash Flows. Our financial derivatives, used for hedging risk, are governed through ISDA master agreements and clearing brokerage agreements. These agreements include stipulations regarding the right of set off in the event that we or our counterparty default on performance obligations. If a default were to occur, both parties have the right to net amounts payable and receivable into a single net settlement between parties. At March 31, 2021 and December 31, 2020, none of our outstanding derivatives contained credit-risk related contingent features that would result in a material adverse impact to us upon any change in our credit ratings. Although we may be required to post margin on our exchange-traded derivatives transacted through a clearing brokerage account, as described below, we do not require our non-cleared derivative counterparties to post collateral with us. Commodity Price Risk Hedging Our core business activities involve certain commodity price-related risks that we manage in various ways, including through the use of derivative instruments. Our policy is to (i) only purchase inventory for which we have a sales market, (ii) structure our sales contracts so that price fluctuations do not materially affect our operating income and (iii) not acquire and hold material physical inventory or derivatives for the purpose of speculating on commodity price changes. The material commodity-related risks inherent in our business activities can be divided into the following general categories: Commodity Purchases and Sales — In the normal course of our operations, we purchase and sell commodities. We use derivatives to manage the associated risks and to optimize profits. As of March 31, 2021, net derivative positions related to these activities included: • A net long position of 9.3 million barrels associated with our crude oil purchases, which was unwound ratably during April 2021 to match monthly average pricing. • A net short time spread position of 6.5 million barrels, which hedges a portion of our anticipated crude oil lease gathering purchases through June 2022. • A net crude oil basis spread position of 1.1 million barrels at multiple locations through December 2022. These derivatives allow us to lock in grade basis differentials. • A net short position of 20.1 million barrels through December 2022 related to anticipated net sales of crude oil and NGL inventory. Natural Gas Processing/NGL Fractionation — We purchase natural gas for processing and operational needs. Additionally, we purchase NGL mix for fractionation and sell the resulting individual specification products (including ethane, propane, butane and condensate). In conjunction with these activities, we hedge the price risk associated with the purchase of the natural gas and the subsequent sale of the individual specification products. The following table summarizes our open derivative positions utilized to hedge the price risk associated with anticipated purchases and sales related to our natural gas processing and NGL fractionation activities as of March 31, 2021: Notional Volume (Short)/Long Remaining Tenor Natural gas purchases 52.5 Bcf March 2022 Propane sales (9.6) MMbls March 2022 Butane sales (3.0) MMbls March 2022 Condensate sales (WTI position) (1.0) MMbls March 2022 Fuel gas requirements (1) 12.5 Bcf December 2022 Power supply requirements (1) 0.8 TWh December 2023 (1) Positions to hedge a portion of our power supply and fuel gas requirements at our Canadian natural gas processing and fractionation plants. Physical commodity contracts that meet the definition of a derivative but are ineligible, or not designated, for the normal purchases and normal sales scope exception are recorded on the balance sheet at fair value, with changes in fair value recognized in earnings. We have determined that substantially all of our physical commodity contracts qualify for the normal purchases and normal sales scope exception. Our commodity derivatives are not designated in a hedging relationship for accounting purposes; as such, changes in the fair value are reported in earnings. A summary of the impact of our commodity derivatives recognized in earnings as follows (in millions): Three Months Ended 2021 2020 Supply and Logistics segment revenues $ (314) $ 149 Field operating costs 39 1 Net gain/(loss) from commodity derivative activity $ (275) $ 150 Our accounting policy is to offset derivative assets and liabilities executed with the same counterparty when a master netting arrangement exists. Accordingly, we also offset derivative assets and liabilities with amounts associated with cash margin. Our exchange-traded derivatives are transacted through clearing brokerage accounts and are subject to margin requirements as established by the respective exchange. On a daily basis, our account equity (consisting of the sum of our cash balance and the fair value of our open derivatives) is compared to our initial margin requirement resulting in the payment or return of variation margin. The following table provides the components of our net broker receivable/(payable) (in millions): March 31, December 31, Initial margin $ 62 $ 91 Variation margin posted/(returned) 259 290 Letters of credit (52) (63) Net broker receivable/(payable) $ 269 $ 318 The following table reflects the Condensed Consolidated Balance Sheet line items that include the fair values of our commodity derivative assets and liabilities and the effect of the collateral netting. Such amounts are presented on a gross basis, before the effects of counterparty netting. However, we have elected to present our commodity derivative assets and liabilities with the same counterparty on a net basis on our Condensed Consolidated Balance Sheet when the legal right of offset exists. Amounts in the table below are presented in millions. March 31, 2021 December 31, 2020 Effect of Collateral Netting Net Carrying Value Presented on the Balance Sheet Effect of Collateral Netting Net Carrying Value Presented on the Balance Sheet Commodity Derivatives Commodity Derivatives Assets Liabilities Assets Liabilities Derivative Assets Other current assets $ 97 $ (261) $ 269 $ 105 $ 71 $ (314) $ 318 $ 75 Other long-term assets, net 4 — — 4 5 — — 5 Derivative Liabilities Other current liabilities 3 (156) — (153) 9 (40) — (31) Other long-term liabilities and deferred credits 1 (58) — (57) — (32) — (32) Total $ 105 $ (475) $ 269 $ (101) $ 85 $ (386) $ 318 $ 17 Interest Rate Risk Hedging We use interest rate derivatives to hedge the benchmark interest rate associated with interest payments occurring as a result of debt issuances. The derivative instruments we use to manage this risk consist of forward starting interest rate swaps and treasury locks. These derivatives are designated as cash flow hedges. As such, changes in fair value are deferred in AOCI and are reclassified to interest expense as we incur the interest expense associated with the underlying debt. The following table summarizes the terms of our outstanding interest rate derivatives as of March 31, 2021 (notional amounts in millions): Hedged Transaction Number and Types of Notional Expected Average Rate Accounting Anticipated interest payments 8 forward starting swaps (30-year) $ 200 6/15/2023 1.38 % Cash flow hedge Anticipated interest payments 8 forward starting swaps (30-year) $ 200 6/14/2024 0.73 % Cash flow hedge As of March 31, 2021, there was a net loss of $187 million deferred in AOCI. The deferred net loss recorded in AOCI is expected to be reclassified to future earnings contemporaneously with (i) the earnings recognition of the underlying hedged commodity transactions or (ii) interest expense accruals associated with underlying debt instruments. We reclassified losses of $3 million and $2 million during the three months ended March 31, 2021 and 2020, respectively. Of the total net loss deferred in AOCI at March 31, 2021, we expect to reclassify a loss of $13 million to earnings in the next twelve months. We estimate that substantially all of the remaining deferred loss will be reclassified to earnings through 2054 as the underlying hedged transactions impact earnings. A portion of these amounts is based on market prices as of March 31, 2021; thus, actual amounts to be reclassified will differ and could vary materially as a result of changes in market conditions. The following table summarizes the net unrealized gain/(loss) recognized in AOCI for derivatives (in millions): Three Months Ended 2021 2020 Interest rate derivatives, net $ 68 $ (79) At March 31, 2021, the net fair value of our interest rate hedges, which were included in “Other long-term assets, net” on our Condensed Consolidated Balance Sheet, totaled $114 million. At December 31, 2020, the net fair value of these hedges totaled $46 million and was included in “Other long-term assets, net.” Currency Exchange Rate Risk Hedging Because a significant portion of our Canadian business is conducted in CAD, we use foreign currency derivatives to minimize the risk of unfavorable changes in exchange rates. These instruments include foreign currency exchange contracts, forwards and options. Our use of foreign currency derivatives include (i) derivatives we use to hedge currency exchange risk created by the use of USD-denominated commodity derivatives to hedge commodity price risk associated with CAD-denominated commodity purchases and sales and (ii) foreign currency exchange contracts we use to manage our Canadian business cash requirements. The following table summarizes our open forward exchange contracts as of March 31, 2021 (in millions): USD CAD Average Exchange Rate Forward exchange contracts that exchange CAD for USD: 2021 $ 167 $ 210 $1.00 - $1.25 Forward exchange contracts that exchange USD for CAD: 2021 $ 227 $ 285 $1.00 - $1.26 These derivatives are not designated in a hedging relationship for accounting purposes. As such, changes in fair value are recognized in earnings as a component of Supply and Logistics segment revenues. For the three months ended March 31, 2021 and 2020, the amounts recognized in earnings for our currency exchange rate hedges were a gain of $1 million and a loss of $6 million, respectively. At March 31, 2021, the net fair value of these currency exchange rate hedges, which was included in “Other current assets” on our Condensed Consolidated Balance Sheet, totaled $1 million. At December 31, 2020, the net fair value of these currency exchange rate hedges, which was included in “Other current assets” on our Condensed Consolidated Balance Sheet, totaled $2 million. Preferred Distribution Rate Reset Option A derivative feature embedded in a contract that does not meet the definition of a derivative in its entirety must be bifurcated and accounted for separately if the economic characteristics and risks of the embedded derivative are not clearly and closely related to those of the host contract. The Preferred Distribution Rate Reset Option of the PAA Series A preferred units is an embedded derivative that must be bifurcated from the related host contract, the PAA partnership agreement, and recorded at fair value on our Condensed Consolidated Balance Sheets. This embedded derivative is not designated in a hedging relationship for accounting purposes and corresponding changes in fair value are recognized in “Other expense, net” in our Condensed Consolidated Statement of Operations. For the three months ended March 31, 2021 and 2020, we recognized a loss of $67 million and a gain of $26 million, respectively. The fair value of the Preferred Distribution Rate Reset Option, which was included in “Other long-term liabilities and deferred credits” on our Condensed Consolidated Balance Sheets, totaled $81 million and $14 million at March 31, 2021 and December 31, 2020, respectively. See Note 12 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for additional information regarding the Series A preferred units and Preferred Distribution Rate Reset Option. Recurring Fair Value Measurements Derivative Financial Assets and Liabilities The following table sets forth by level within the fair value hierarchy our financial assets and liabilities that were accounted for at fair value on a recurring basis (in millions): Fair Value as of March 31, 2021 Fair Value as of December 31, 2020 Recurring Fair Value Measures (1) Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Commodity derivatives $ (241) $ (118) $ (11) $ (370) $ (143) $ (143) $ (15) $ (301) Interest rate derivatives — 114 — 114 — 46 — 46 Foreign currency derivatives — 1 — 1 — 2 — 2 Preferred Distribution Rate Reset Option — — (81) (81) — — (14) (14) Total net derivative asset/(liability) $ (241) $ (3) $ (92) $ (336) $ (143) $ (95) $ (29) $ (267) (1) Derivative assets and liabilities are presented above on a net basis but do not include related cash margin deposits. Level 1 Level 1 of the fair value hierarchy includes exchange-traded commodity derivatives and over-the-counter commodity contracts such as futures and swaps. The fair value of exchange-traded commodity derivatives and over-the-counter commodity contracts is based on unadjusted quoted prices in active markets. Level 2 Level 2 of the fair value hierarchy includes exchange-cleared commodity derivatives and over-the-counter commodity, interest rate and foreign currency derivatives that are traded in observable markets with less volume and transaction frequency than active markets. In addition, it includes certain physical commodity contracts. The fair values of these derivatives are corroborated with market observable inputs. Level 3 Level 3 of the fair value hierarchy includes certain physical commodity and other contracts, over-the-counter options and the Preferred Distribution Rate Reset Option contained in PAA’s partnership agreement which is classified as an embedded derivative. The fair values of our Level 3 physical commodity and other contracts and over-the-counter options are based on valuation models utilizing significant timing estimates, which involve management judgment, and pricing inputs from observable and unobservable markets with less volume and transaction frequency than active markets. Significant deviations from these estimates and inputs could result in a material change in fair value. We report unrealized gains and losses associated with these contracts in our Condensed Consolidated Statements of Operations as Supply and Logistics segment revenues. The fair value of the embedded derivative feature contained in PAA’s partnership agreement is based on a valuation model that estimates the fair value of the Series A preferred units with and without the Preferred Distribution Rate Reset Option. This model contains inputs, including PAA’s common unit price, ten-year U.S. Treasury rates, default probabilities and timing estimates, some of which involve management judgment. A significant change in these inputs could result in a material change in fair value to this embedded derivative feature. Rollforward of Level 3 Net Asset/(Liability) The following table provides a reconciliation of changes in fair value of the beginning and ending balances for our derivatives classified as Level 3 (in millions): Three Months Ended 2021 2020 Beginning Balance $ (29) $ (51) Net losses for the period included in earnings (67) (10) Settlements 4 — Ending Balance $ (92) $ (61) Change in unrealized losses included in earnings relating to Level 3 derivatives still held at the end of the period $ (67) $ (10) |
Related Party Transactions
Related Party Transactions | 3 Months Ended |
Mar. 31, 2021 | |
Related Party Transactions [Abstract] | |
Related Party Transactions | Related Party Transactions See Note 17 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for a complete discussion of related parties, including the determination of our related parties and nature of involvement with such related parties. During the three months ended March 31, 2021 and 2020, we recognized sales and transportation revenues, purchased petroleum products and utilized transportation and storage services from our related parties. These transactions were conducted at posted tariff rates or prices that we believe approximate market. The impact to our Condensed Consolidated Statements of Operations from these transactions is included below (in millions): Three Months Ended 2021 2020 Revenues from related parties (1) $ 7 $ 23 Purchases and related costs from related parties (1) $ 90 $ 129 (1) Crude oil purchases that are part of inventory exchanges under buy/sell transactions are netted with the related sales, with any margin presented in “Purchases and related costs” in our Condensed Consolidated Statements of Operations. Our receivable and payable amounts with these related parties as reflected on our Condensed Consolidated Balance Sheets were as follows (in millions): March 31, December 31, Trade accounts receivable and other receivables, net from related parties (1) $ 25 $ 34 Trade accounts payable to related parties (1) (2) $ 79 $ 88 (1) Includes amounts related to crude oil purchases and sales, transportation and storage services and amounts owed to us or advanced to us related to investment capital projects of equity method investees where we serve as construction manager. (2) We have agreements to store crude oil at facilities and transport crude oil or utilize capacity on pipelines that are owned by equity method investees. A portion of our commitment to transport is supported by crude oil buy/sell or other agreements with third parties with commensurate quantities. |
Commitments and Contingencies
Commitments and Contingencies | 3 Months Ended |
Mar. 31, 2021 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies | Commitments and Contingencies Loss Contingencies — General To the extent we are able to assess the likelihood of a negative outcome for a contingency, our assessments of such likelihood range from remote to probable. If we determine that a negative outcome is probable and the amount of loss is reasonably estimable, we accrue an undiscounted liability equal to the estimated amount. If a range of probable loss amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then we accrue an undiscounted liability equal to the minimum amount in the range. In addition, we estimate legal fees that we expect to incur associated with loss contingencies and accrue those costs when they are material and probable of being incurred. We do not record a contingent liability when the likelihood of loss is probable but the amount cannot be reasonably estimated or when the likelihood of loss is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is reasonably possible and the impact would be material to our consolidated financial statements, we disclose the nature of the contingency and, where feasible, an estimate of the possible loss or range of loss. Legal Proceedings — General In the ordinary course of business, we are involved in various legal proceedings, including those arising from regulatory and environmental matters. In connection with determining the probability of loss associated with such legal proceedings and whether any potential losses associated therewith are estimable, we take into account what we believe to be all relevant known facts and circumstances, and what we believe to be reasonable assumptions regarding the application of those facts and circumstances to existing agreements, laws and regulations. Although we are insured against various risks to the extent we believe it is prudent, there is no assurance that the nature and amount of such insurance will be adequate, in every case, to fully protect us from losses arising from current or future legal proceedings. Accordingly, we can provide no assurance that the outcome of the various legal proceedings that we are currently involved in, or will become involved with in the future, will not, individually or in the aggregate, have a material adverse effect on our consolidated financial condition, results of operations or cash flows. Environmental — General Although we have made significant investments in our maintenance and integrity programs, we have experienced (and likely will experience future) releases of hydrocarbon products into the environment from our pipeline, rail, storage and other facility operations. These releases can result from accidents or from unpredictable man-made or natural forces and may reach surface water bodies, groundwater aquifers or other sensitive environments. Damages and liabilities associated with any such releases from our existing or future assets could be significant and could have a material adverse effect on our consolidated financial condition, results of operations or cash flows. We record environmental liabilities when environmental assessments and/or remedial efforts are probable and the amounts can be reasonably estimated. Generally, our recording of these accruals coincides with our completion of a feasibility study or our commitment to a formal plan of action. We do not discount our environmental remediation liabilities to present value. We also record environmental liabilities assumed in business combinations based on the estimated fair value of the environmental obligations caused by past operations of the acquired company. We record receivables for amounts we believe are recoverable from insurance or from third parties under indemnification agreements in the period that we determine the costs are probable of recovery. Environmental expenditures that pertain to current operations or to future revenues are expensed or capitalized consistent with our capitalization policy for property and equipment. Expenditures that result from the remediation of an existing condition caused by past operations and that do not contribute to current or future profitability are expensed. At March 31, 2021, our estimated undiscounted reserve for environmental liabilities (including liabilities related to the Line 901 incident, as discussed further below) totaled $160 million, of which $114 million was classified as short-term and $46 million was classified as long-term. At December 31, 2020, our estimated undiscounted reserve for environmental liabilities (including liabilities related to the Line 901 incident) totaled $141 million, of which $94 million was classified as short-term and $47 million was classified as long-term. Such short-term liabilities are reflected in “Trade accounts payable” and “Other current liabilities” and long-term liabilities are reflected in “Other long-term liabilities and deferred credits” on our Condensed Consolidated Balance Sheets. At March 31, 2021, we had recorded receivables totaling $114 million for amounts probable of recovery under insurance and from third parties under indemnification agreements, of which $113 million was classified as short-term and $1 million was classified as long-term. At December 31, 2020, we had recorded $97 million of such receivables, of which $96 million was classified as short-term and $1 million was classified as long-term. Such short- and long-term receivables are reflected in “Trade accounts receivable and other receivables, net” and “Other long-term assets, net,” respectively, on our Condensed Consolidated Balance Sheets. In some cases, the actual cash expenditures associated with these liabilities may not occur for three years or longer. Our estimates used in determining these reserves are based on information currently available to us and our assessment of the ultimate outcome. Among the many uncertainties that impact our estimates are the necessary regulatory approvals for, and potential modification of, our remediation plans, the limited amount of data available upon initial assessment of the impact of soil or water contamination, changes in costs associated with environmental remediation services and equipment and the possibility of existing or future legal claims giving rise to additional liabilities. Therefore, although we believe that the reserve is adequate, actual costs incurred (which may ultimately include costs for contingencies that are currently not reasonably estimable or costs for contingencies where the likelihood of loss is currently believed to be only reasonably possible or remote) may be in excess of the reserve and may potentially have a material adverse effect on our consolidated financial condition, results of operations or cash flows. Specific Legal, Environmental or Regulatory Matters Line 901 Incident . In May 2015, we experienced a crude oil release from our Las Flores to Gaviota Pipeline (Line 901) in Santa Barbara County, California. A portion of the released crude oil reached the Pacific Ocean at Refugio State Beach through a drainage culvert. Following the release, we shut down the pipeline and initiated our emergency response plan. A Unified Command, which included the United States Coast Guard, the EPA, the State of California Department of Fish and Wildlife (“CDFW”), the California Office of Spill Prevention and Response and the Santa Barbara Office of Emergency Management, was established for the response effort. Clean-up and remediation operations with respect to impacted shoreline and other areas has been determined by the Unified Command to be complete, and the Unified Command has been dissolved. Our estimate of the amount of oil spilled, based on relevant facts, data and information, and as set forth in the Consent Decree described below, is approximately 2,934 barrels; of this amount, we estimate that 598 barrels reached the Pacific Ocean. As a result of the Line 901 incident, several governmental agencies and regulators initiated investigations into the Line 901 incident, various claims have been made against us and a number of lawsuits have been filed against us, the majority of which have been resolved. Set forth below is a brief summary of actions and matters that are currently pending or recently resolved: As the “responsible party” for the Line 901 incident we are liable for various costs and for certain natural resource damages under the Oil Pollution Act. In this regard, following the Line 901 incident, we entered into a cooperative Natural Resource Damage Assessment (“NRDA”) process with the federal and state agencies designated or authorized by law to act as trustees for the natural resources of the United States and the State of California (collectively, the “Trustees”). Additionally, various government agencies sought to collect civil fines and penalties under applicable state and federal regulations. On March 13, 2020, the United States and the People of the State of California filed a civil complaint against Plains All American Pipeline, L.P. and Plains Pipeline L.P. along with a pre-negotiated settlement agreement in the form of a Consent Decree (the “Consent Decree”) that was signed by the United States Department of Justice, Environmental and Natural Resources Division, the United States Department of Transportation, Pipeline and Hazardous Materials Safety Administration, the EPA, CDFW, the California Department of Parks and Recreation, the California State Lands Commission, the California Department of Forestry and Fire Protection’s Office of the State Fire Marshal, Central Coast Regional Water Quality Control Board, and Regents of the University of California. The Consent Decree was approved and entered by the Federal District Court for the Central District of California on October 14, 2020. Pursuant to the terms of the Consent Decree, Plains paid $24 million in civil penalties and $22.325 million as compensation for injuries to, destruction of, loss of, or loss of use of natural resources resulting from the Line 901 incident. The Consent Decree also contains requirements for implementing certain agreed-upon injunctive relief, as well as requirements for potentially restarting Line 901 and the Sisquoc to Pentland portion of Line 903. The Consent Decree resolved all regulatory claims related to the incident. Following an investigation and grand jury proceedings, in May of 2016, PAA was charged by a California state grand jury, pursuant to an indictment filed in California Superior Court, Santa Barbara County (the “May 2016 Indictment”), with alleged violations of California law in connection with the Line 901 incident. Fifteen charges from the May 2016 Indictment were the subject of a jury trial in California Superior Court in Santa Barbara County, and the jury returned a verdict on September 7, 2018, pursuant to which we were (i) found guilty on one felony discharge count and eight misdemeanor counts (which included one reporting count, one strict liability discharge count and six strict liability animal takings counts) and (ii) found not guilty on one strict liability animal takings count. The remaining counts were subsequently dismissed by the Court. On April 25, 2019, PAA was sentenced to pay fines and penalties in the aggregate amount of just under $3.35 million for the convictions covered by the September 2018 jury verdict (the “2019 Sentence”). The fines and penalties imposed in connection with the 2019 Sentence have been paid. The only pending matter relating to these proceedings is that the Superior Court indicated that it would conduct further hearings in 2021 on the issue of whether there were any “direct victims” of the spill that are entitled to restitution under applicable law. Shortly following the Line 901 incident, we established a claims line and encouraged any parties that were damaged by the release to contact us to discuss their damage claims. We received a number of claims through the claims line and we have processed those claims and made payments as appropriate. Nine class action lawsuits were filed against us; however, after various claims were either dismissed or consolidated, two proceedings remain pending in the United States District Court for the Central District of California. In the first proceeding, the plaintiffs claim two different classes of claimants were damaged by the release: (i) commercial fishermen who landed fish in certain specified fishing blocks in the waters off the coast of Southern California or persons or businesses who resold commercial seafood caught in those areas; and (ii) owners and lessees of residential beachfront properties, or properties with a private easement to a beach, where plaintiffs claim oil from the spill washed up. We are vigorously defending against those claims. A September 2020 trial date initially set by the Court has been postponed indefinitely due to COVID-19 related trial suspensions. In the second proceeding, the plaintiffs seek a declaratory judgment that Plains’ right-of-way agreements would not allow Plains to lay a new pipeline to replace Line 901 and/or the non-operating segment of Line 903 without paying additional compensation. No trial date has been set in that action. In addition, four unitholder derivative lawsuits were filed by certain purported investors in PAA against PAGP and certain of PAA’s affiliates, officers and directors. After various claims were either dismissed or consolidated, one proceeding against PAGP remains pending in Delaware Chancery Court. Generally, the plaintiffs claim that PAGP failed to exercise proper oversight over the Partnership’s pipeline integrity efforts. We will vigorously defend the claim. No trial date has been set in this action. We have also received several other individual lawsuits and claims from companies, governmental agencies and individuals alleging damages arising out of the Line 901 incident. These lawsuits and claims generally seek restitution, compensatory and punitive damages, and/or injunctive relief. The majority of these lawsuits have been settled or dismissed by the court. Remaining claims include claims for lost revenue or profit asserted by a former oil producer that declared bankruptcy and shut in its offshore production platform following the Line 901 incident, a state agency that received royalties on oil produced from that platform until it was abandoned by its owner, and various companies and individuals who provided labor, goods, or services associated with oil production activities they claim were disrupted following the Line 901 incident. We are vigorously defending these suits. We may be subject to additional claims and lawsuits, which could materially impact the liabilities and costs we currently expect to incur as a result of the Line 901 incident. Taking the foregoing into account, as of March 31, 2021, we estimate that the aggregate total costs we have incurred or will incur with respect to the Line 901 incident will be approximately $485 million, which estimate includes actual and projected emergency response and clean-up costs, natural resource damage assessments, fines and penalties payable pursuant to the Consent Decree and certain third party claims settlements, as well as estimates for certain legal fees. We accrue such estimates of aggregate total costs to “Field operating costs” in our Condensed Consolidated Statements of Operations. This estimate considers our prior experience in environmental investigation and remediation matters and available data from, and in consultation with, our environmental and other specialists, as well as currently available facts and presently enacted laws and regulations. We have made assumptions for (i) the resolution of certain third party claims and lawsuits, but excluding claims and lawsuits with respect to which losses are not probable and reasonably estimable, and excluding future claims and lawsuits and (ii) the nature, extent and cost of legal services that will be required in connection with all lawsuits, claims and other matters requiring legal or expert advice associated with the Line 901 incident. Our estimate does not include any lost revenue associated with the shutdown of Line 901 or 903 and does not include any liabilities or costs that are not reasonably estimable at this time or that relate to contingencies where we currently regard the likelihood of loss as being only reasonably possible or remote. We believe we have accrued adequate amounts for all probable and reasonably estimable costs; however, this estimate is subject to uncertainties associated with the assumptions that we have made. For example, the amount of time it takes for us to resolve all of the current and future lawsuits and claims that relate to the Line 901 incident could turn out to be significantly longer than we have assumed, and as a result the costs we incur for legal services could be significantly higher than we have estimated. Accordingly, our assumptions and estimates may turn out to be inaccurate and our total costs could turn out to be materially higher; therefore, we can provide no assurance that we will not have to accrue significant additional costs in the future with respect to the Line 901 incident. As of March 31, 2021, we had a remaining undiscounted gross liability of $105 million related to this event, which is reflected in “Trade accounts payable” and “Other current liabilities” on our Condensed Consolidated Balance Sheet. We maintain insurance coverage, which is subject to certain exclusions and deductibles, in the event of such environmental liabilities. Subject to such exclusions and deductibles, we believe that our coverage is adequate to cover the current estimated total emergency response and clean-up costs, claims settlement costs and remediation costs and we believe that this coverage is also adequate to cover any potential increase in the estimates for these costs that exceed the amounts currently identified. Through March 31, 2021, we had collected, subject to customary reservations, $250 million out of the approximate $360 million of release costs that we believe are probable of recovery from insurance carriers, net of deductibles. Therefore, as of March 31, 2021, we have recognized a receivable of approximately $110 million for the portion of the release costs that we believe is probable of recovery from insurance, net of deductibles and amounts already collected. Such amount is recognized as a current asset in “Trade accounts receivable and other receivables, net” on our Condensed Consolidated Balance Sheet. We have completed the required clean-up and remediation work as determined by the Unified Command and the Unified Command has been dissolved; however, we expect to make payments for additional costs associated with restoration of the impacted areas, as well as legal, professional and regulatory costs during future periods. |
Operating Segments
Operating Segments | 3 Months Ended |
Mar. 31, 2021 | |
Segment Reporting [Abstract] | |
Operating Segments | Operating Segments We manage our operations through three operating segments: Transportation, Facilities and Supply and Logistics. See Note 3 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for a summary of the types of products and services from which each segment derives its revenues. Our CODM (our Chief Executive Officer) evaluates segment performance based on measures including Segment Adjusted EBITDA (as defined below) and maintenance capital investment. We define Segment Adjusted EBITDA as revenues and equity earnings in unconsolidated entities less (a) purchases and related costs, (b) field operating costs and (c) segment general and administrative expenses, plus our proportionate share of the depreciation and amortization expense of unconsolidated entities, and further adjusted for certain selected items including (i) gains and losses on derivative instruments that are related to underlying activities in another period (or the reversal of such adjustments from a prior period), gains and losses on derivatives that are related to investing activities (such as the purchase of linefill) and inventory valuation adjustments, as applicable, (ii) long-term inventory costing adjustments, (iii) charges for obligations that are expected to be settled with the issuance of equity instruments, (iv) amounts related to deficiencies associated with minimum volume commitments, net of the applicable amounts subsequently recognized into revenue and (v) other items that our CODM believes are integral to understanding our core segment operating performance. Segment Adjusted EBITDA excludes depreciation and amortization. Maintenance capital consists of capital expenditures for the replacement and/or refurbishment of partially or fully depreciated assets in order to maintain the operating and/or earnings capacity of our existing assets. The following tables reflect certain financial data for each segment (in millions): Transportation Facilities Supply and Intersegment Adjustment Total Three Months Ended March 31, 2021 Revenues: External customers (1) $ 234 $ 163 $ 8,083 $ (97) $ 8,383 Intersegment (2) 253 108 — 97 458 Total revenues of reportable segments $ 487 $ 271 $ 8,083 $ — $ 8,841 Equity earnings in unconsolidated entities $ 86 $ 2 $ — $ 88 Segment Adjusted EBITDA $ 388 $ 171 $ (13) $ 546 Maintenance capital $ 26 $ 6 $ 3 $ 35 Three Months Ended March 31, 2020 Revenues: External customers (1) $ 297 $ 175 $ 7,907 $ (110) $ 8,269 Intersegment (2) 282 138 1 110 531 Total revenues of reportable segments $ 579 $ 313 $ 7,908 $ — $ 8,800 Equity earnings in unconsolidated entities $ 108 $ 2 $ — $ 110 Segment Adjusted EBITDA $ 442 $ 210 $ 141 $ 793 Maintenance capital $ 34 $ 14 $ 3 $ 51 (1) Transportation revenues from External customers include tariff revenue from transporting volumes associated with certain inventory exchanges with our customers where our Supply and Logistics segment has transacted the inventory exchange and serves as the shipper on our pipeline systems. See Note 3 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for a discussion of our related accounting policy. We have included an estimate of the revenues from these inventory exchanges in our Transportation segment revenues from External customers presented above and adjusted those revenues out such that Total revenues from External customers reconciles to our Condensed Consolidated Statements of Operations. This presentation is consistent with the information provided to our CODM. (2) Segment revenues include intersegment amounts that are eliminated in Purchases and related costs and Field operating costs in our Condensed Consolidated Statements of Operations. Intersegment activities are conducted at posted tariff rates where applicable, or otherwise at rates similar to those charged to third parties or rates that we believe approximate market at the time the agreement is executed or renegotiated. Segment Adjusted EBITDA Reconciliation The following table reconciles Segment Adjusted EBITDA to Net income/(loss) attributable to PAGP (in millions): Three Months Ended 2021 2020 Segment Adjusted EBITDA $ 546 $ 793 Adjustments: (1) Depreciation and amortization of unconsolidated entities (2) (20) (17) Gains/(losses) from derivative activities and inventory valuation adjustments (3) 198 (30) Long-term inventory costing adjustments (4) 41 (115) Deficiencies under minimum volume commitments, net (5) 32 2 Equity-indexed compensation expense (6) (5) (4) Net gain on foreign currency revaluation (7) 1 13 Significant acquisition-related expenses (8) — (3) Unallocated general and administrative expenses (1) (1) Depreciation and amortization (178) (169) Gains/(losses) on asset sales and asset impairments, net (2) (619) Goodwill impairment losses — (2,515) Gain on/(impairment of) investments in unconsolidated entities, net — (22) Interest expense, net (107) (108) Other expense, net (60) (31) Income/(loss) before tax 445 (2,826) Income tax (expense)/benefit (53) 134 Net income/(loss) 392 (2,692) Net (income)/loss attributable to noncontrolling interests (322) 2,111 Net income/(loss) attributable to PAGP $ 70 $ (581) (1) Represents adjustments utilized by our CODM in the evaluation of segment results. (2) Includes our proportionate share of the depreciation and amortization of unconsolidated entities. (3) We use derivative instruments for risk management purposes and our related processes include specific identification of hedging instruments to an underlying hedged transaction. Although we identify an underlying transaction for each derivative instrument we enter into, there may not be an accounting hedge relationship between the instrument and the underlying transaction. In the course of evaluating our results, we identify differences in the timing of earnings from the derivative instruments and the underlying transactions and exclude the related gains and losses in determining Segment Adjusted EBITDA such that the earnings from the derivative instruments and the underlying transactions impact Segment Adjusted EBITDA in the same period. In addition, we exclude gains and losses on derivatives that are related to investing activities, such as the purchase of linefill. (4) We carry crude oil and NGL inventory that is comprised of minimum working inventory requirements in third-party assets and other working inventory that is needed for our commercial operations. We consider this inventory necessary to conduct our operations and we intend to carry this inventory for the foreseeable future. Therefore, we classify this inventory as long-term on our balance sheet and do not hedge the inventory with derivative instruments (similar to linefill in our own assets). We exclude the impact of changes in the average cost of the long-term inventory (that result from fluctuations in market prices) and write-downs of such inventory that result from price declines from Segment Adjusted EBITDA. (5) We, and certain of our equity method investments, have certain agreements that require counterparties to deliver, transport or throughput a minimum volume over an agreed upon period. Substantially all of such agreements were entered into with counterparties to economically support the return on our capital expenditure necessary to construct the related asset. Some of these agreements include make-up rights if the minimum volume is not met. We record a receivable from the counterparty in the period that services are provided or when the transaction occurs, including amounts for deficiency obligations from counterparties associated with minimum volume commitments. If a counterparty has a make-up right associated with a deficiency, we defer the revenue attributable to the counterparty’s make-up right and subsequently recognize the revenue at the earlier of when the deficiency volume is delivered or shipped, when the make-up right expires or when it is determined that the counterparty’s ability to utilize the make-up right is remote. We include the impact of amounts billed to counterparties for their deficiency obligation, net of applicable amounts subsequently recognized into revenue, as a selected item impacting comparability. Our CODM views the inclusion of the contractually committed revenues associated with that period as meaningful to Segment Adjusted EBITDA as the related asset has been constructed, is standing ready to provide the committed service and the fixed operating costs are included in the current period results. (6) Our total equity-indexed compensation expense includes expense associated with awards that will be settled in PAA common units and awards that will be settled in cash. The awards that will be settled in PAA common units are included in PAA’s diluted net income per unit calculation when the applicable performance criteria have been met. We exclude compensation expense associated with these awards in determining Segment Adjusted EBITDA as the dilutive impact of the outstanding awards is included in PAA’s diluted net income per unit calculation, as applicable. The portion of compensation expense associated with awards that will settle in cash is not excluded in determining Segment Adjusted EBITDA. See Note 18 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for a discussion regarding our equity-indexed compensation plans. (7) During the periods presented, there were fluctuations in the value of CAD to USD, resulting in the realization of foreign exchange gains and losses on the settlement of foreign currency transactions as well as the revaluation of monetary assets and liabilities denominated in a foreign currency. These gains and losses are not integral to our core operating performance and were therefore excluded in determining Segment Adjusted EBITDA. See Note 8 for discussion regarding our currency exchange rate risk hedging activities. |
Summary of Significant Accoun_2
Summary of Significant Accounting Policies (Policies) | 3 Months Ended |
Mar. 31, 2021 | |
Accounting Policies [Abstract] | |
Restricted Cash | Restricted CashRestricted cash includes cash held by us that is unavailable for general use and is comprised of amounts advanced to us by certain equity method investees related to the construction of fixed assets where we serve as construction manager. |
Recent Accounting Pronouncements | Recent Accounting Pronouncements Except as discussed below and in our 2020 Annual Report on Form 10-K, there have been no new accounting pronouncements that have become effective or have been issued during the three months ended March 31, 2021 that are of significance or potential significance to us. Accounting Standards Updates Adopted During the Period We adopted the ASU listed below effective January 1, 2021 and our adoption did not have a material impact on our financial position, results of operations or cash flows (see Note 2 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for additional information regarding this ASU): • ASU 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes. |
Summary of Significant Accoun_3
Summary of Significant Accounting Policies (Tables) | 3 Months Ended |
Mar. 31, 2021 | |
Accounting Policies [Abstract] | |
Reconciliation of cash and cash equivalents and restricted cash | The following table presents a reconciliation of cash and cash equivalents and restricted cash reported on our Condensed Consolidated Balance Sheets that sum to the total of the amounts shown on our Condensed Consolidated Statements of Cash Flows (in millions): March 31, December 31, Cash and cash equivalents $ 32 $ 25 Restricted cash 26 38 Total cash and cash equivalents and restricted cash $ 58 $ 63 |
Revenues and Accounts Receiva_2
Revenues and Accounts Receivable (Tables) | 3 Months Ended |
Mar. 31, 2021 | |
Disaggregation of Revenue [Line Items] | |
Disaggregation of revenue | The following disclosures only include information regarding revenues associated with consolidated entities; revenues from entities accounted for by the equity method are not included. The following tables present the reconciliation of our revenues from contracts with customers (as described above for each segment) to segment revenues and total revenues as disclosed in our Condensed Consolidated Statements of Operations (in millions): Three Months Ended March 31, 2021 Transportation Facilities Supply and Total Revenues from contracts with customers $ 446 $ 254 $ 8,395 $ 9,095 Other items in revenues 41 17 (312) (254) Total revenues of reportable segments $ 487 $ 271 $ 8,083 $ 8,841 Intersegment revenues (458) Total revenues $ 8,383 Three Months Ended March 31, 2020 Transportation Facilities Supply and Total Revenues from contracts with customers $ 573 $ 305 $ 7,750 $ 8,628 Other items in revenues 6 8 158 172 Total revenues of reportable segments $ 579 $ 313 $ 7,908 $ 8,800 Intersegment revenues (531) Total revenues $ 8,269 |
Contract with customer, counterparty deficiencies | The following table presents counterparty deficiencies associated with contracts with customers and buy/sell arrangements that include minimum volume commitments for which we had remaining performance obligations and the customers still had the ability to meet their obligations (in millions): Counterparty Deficiencies Financial Statement Classification March 31, December 31, Billed and collected Liability $ 47 $ 73 Unbilled (1) N/A 24 4 Total $ 71 $ 77 (1) Amounts were related to deficiencies for which the counterparties had not met their contractual minimum commitments and are not reflected in our Condensed Consolidated Financial Statements as we had not yet billed or collected such amounts. |
Contracts with customers, change in contract liability balance | The following table presents the change in the liability balance associated with contracts with customers (in millions): Contract Liabilities Balance at December 31, 2020 $ 501 Amounts recognized as revenue (1) (380) Additions (2) 373 Balance at March 31, 2021 $ 494 (1) Includes approximately $361 million associated with crude oil sales agreements that were entered into in the fourth quarter of 2020 in conjunction with storage arrangements and future inventory exchanges. (2) Includes approximately $346 million associated with crude oil sales agreements that were entered into in the first quarter of 2021 in conjunction with storage arrangements and future inventory exchanges. Such amount is expected to be recognized as revenue in the second quarter of 2021. The following is a reconciliation of trade accounts receivable from revenues from contracts with customers to total Trade accounts receivable and other receivables, net as presented on our Condensed Consolidated Balance Sheets (in millions): March 31, December 31, 2020 Trade accounts receivable arising from revenues from contracts with customers $ 3,140 $ 2,317 Other trade accounts receivables and other receivables (1) 3,582 2,818 Impact due to contractual rights of offset with counterparties (3,321) (2,582) Trade accounts receivable and other receivables, net $ 3,401 $ 2,553 (1) The balance is comprised primarily of accounts receivable associated with buy/sell arrangements that are not within the scope of ASC 606. |
Remaining performance obligations | The following table presents the amount of consideration associated with remaining performance obligations for the population of contracts with external customers meeting the presentation requirements as of March 31, 2021 (in millions): Remainder of 2021 2022 2023 2024 2025 2026 and Thereafter Pipeline revenues supported by minimum volume commitments and capacity agreements (1) $ 135 $ 171 $ 171 $ 146 $ 126 $ 456 Storage, terminalling and throughput agreement revenues 275 302 220 179 116 332 Total $ 410 $ 473 $ 391 $ 325 $ 242 $ 788 |
Supply and Logistics | |
Disaggregation of Revenue [Line Items] | |
Disaggregation of revenue | The following tables present our Supply and Logistics, Transportation and Facilities segment revenues from contracts with customers disaggregated by type of activity (in millions): Three Months Ended 2021 2020 Supply and Logistics segment revenues from contracts with customers Crude oil transactions $ 7,711 $ 7,322 NGL and other transactions 684 428 Total Supply and Logistics segment revenues from contracts with customers $ 8,395 $ 7,750 |
Transportation | |
Disaggregation of Revenue [Line Items] | |
Disaggregation of revenue | Three Months Ended 2021 2020 Transportation segment revenues from contracts with customers Tariff activities: Crude oil pipelines $ 397 $ 512 NGL pipelines 27 26 Total tariff activities 424 538 Trucking 22 35 Total Transportation segment revenues from contracts with customers $ 446 $ 573 |
Facilities | |
Disaggregation of Revenue [Line Items] | |
Disaggregation of revenue | Three Months Ended 2021 2020 Facilities segment revenues from contracts with customers Crude oil, NGL and other terminalling and storage $ 170 $ 182 NGL and natural gas processing and fractionation 73 109 Rail load / unload 11 14 Total Facilities segment revenues from contracts with customers $ 254 $ 305 |
Net Income Per Class A Share (T
Net Income Per Class A Share (Tables) | 3 Months Ended |
Mar. 31, 2021 | |
Earnings Per Share [Abstract] | |
Calculation of basic and diluted net income/(loss) per Class A share | The following table sets forth the computation of basic and diluted net income/(loss) per Class A share (in millions, except per share data): Three Months Ended 2021 2020 Basic and Diluted Net Income/(Loss) per Class A Share Net income/(loss) attributable to PAGP $ 70 $ (581) Basic and diluted weighted average Class A shares outstanding 194 183 Basic and diluted net income/(loss) per Class A share $ 0.36 $ (3.18) |
Inventory, Linefill and Base _2
Inventory, Linefill and Base Gas and Long-term Inventory (Tables) | 3 Months Ended |
Mar. 31, 2021 | |
Inventory, Linefill and Base Gas and Long-term Inventory | |
Schedule of inventory, linefill and base gas and long-term inventory | Inventory, linefill and base gas and long-term inventory consisted of the following (barrels and natural gas volumes in thousands and carrying value in millions): March 31, 2021 December 31, 2020 Volumes Unit of Carrying Price/ Unit (1) Volumes Unit of Carrying Price/ Unit (1) Inventory Crude oil 8,896 barrels $ 373 $ 41.93 13,450 barrels $ 441 $ 32.79 NGL 4,872 barrels 105 $ 21.55 12,302 barrels 199 $ 16.18 Other N/A 6 N/A N/A 7 N/A Inventory subtotal 484 647 Linefill and base gas Crude oil 14,653 barrels 828 $ 56.51 14,669 barrels 828 $ 56.45 NGL 1,650 barrels 45 $ 27.27 1,640 barrels 44 $ 26.83 Natural gas 25,576 Mcf 110 $ 4.30 25,576 Mcf 110 $ 4.30 Linefill and base gas subtotal 983 982 Long-term inventory Crude oil 2,669 barrels 154 $ 57.70 2,499 barrels 111 $ 44.42 NGL 1,105 barrels 24 $ 21.72 1,185 barrels 19 $ 16.03 Long-term inventory subtotal 178 130 Total $ 1,645 $ 1,759 (1) Price per unit of measure is comprised of a weighted average associated with various grades, qualities and locations. Accordingly, these prices may not coincide with any published benchmarks for such products. |
Debt (Tables)
Debt (Tables) | 3 Months Ended |
Mar. 31, 2021 | |
Debt Disclosure [Abstract] | |
Schedule of debt | Debt consisted of the following (in millions): March 31, December 31, SHORT-TERM DEBT PAA commercial paper notes, bearing a weighted-average interest rate of 0.6% and 0.7%, respectively (1) $ 137 $ 547 PAA senior secured hedged inventory facility, bearing a weighted-average interest rate of 1.2% (1) — 167 Other 117 117 Total short-term debt 254 831 LONG-TERM DEBT PAA senior notes, net of unamortized discounts and debt issuance costs of $60 and $62, respectively 9,073 9,071 PAA GO Zone term loans, net of debt issuance costs of $1 and $1, respectively, bearing a weighted-average interest rate of 1.3% and 1.3%, respectively 199 199 Other 66 112 Total long-term debt 9,338 9,382 Total debt (2) $ 9,592 $ 10,213 (1) We classified these commercial paper notes as short-term as of March 31, 2021 and December 31, 2020, respectively, and these credit facility borrowings as short-term as of December 31, 2020, as these notes and borrowings were primarily designated as working capital borrowings, were required to be repaid within one year and were primarily for hedged NGL and crude oil inventory and NYMEX and ICE margin deposits. |
Partners' Capital and Distrib_2
Partners' Capital and Distributions (Tables) | 3 Months Ended |
Mar. 31, 2021 | |
Partners' Capital and Distributions | |
Schedule of activity for Class A shares, Class B shares and Class C shares | The following tables present the activity for our Class A shares, Class B shares and Class C shares: Class A Shares Class B Shares Class C Shares Outstanding at December 31, 2020 194,051,436 50,640,192 547,717,762 Conversion of AAP Management Units (1) — 414,608 — Exchange Right exercises (1) 46,879 (46,879) — Redemption Right exercises (1) — (229,931) 229,931 Repurchase of common units by a subsidiary under Common Equity Repurchase Program (2) — — (350,000) Other — — 25,431 Outstanding at March 31, 2021 194,098,315 50,777,990 547,623,124 Class A Shares Class B Shares Class C Shares Outstanding at December 31, 2019 182,138,592 65,785,702 549,538,139 Conversion of AAP Management Units (1) — 559,768 — Exchange Right exercises (1) 2,101,487 (2,101,487) — Redemption Right exercises (1) — (1,206,599) 1,206,599 Other — — 24,431 Outstanding at March 31, 2020 184,240,079 63,037,384 550,769,169 (1) See Note 12 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for information regarding conversions of AAP Management Units, Exchange Rights and Redemption Rights. (2) Trades for these units were executed in late December 2020, but settled in early January 2021. |
AAP | |
Partners' Capital and Distributions | |
Schedule of distributions | The following table details the distributions to AAP’s partners paid during or pertaining to the first three months of 2021 from distributions received from PAA (in millions): Distributions to AAP ’ s Partners Distribution Payment Date Noncontrolling Interests PAGP Total Cash Distribution May 14, 2021 (1) $ 9 $ 35 $ 44 February 12, 2021 $ 9 $ 35 $ 44 (1) Payable to unitholders of record at the close of business on April 30, 2021 for the period from January 1, 2021 through March 31, 2021. |
Class A Shares | |
Partners' Capital and Distributions | |
Schedule of distributions | The following table details distributions to our Class A shareholders paid during or pertaining to the first three months of 2021 (in millions, except per share data): Distribution Payment Date Distributions to Distributions per May 14, 2021 (1) $ 35 $ 0.18 February 12, 2021 $ 35 $ 0.18 (1) Payable to shareholders of record at the close of business on April 30, 2021 for the period from January 1, 2021 through March 31, 2021. |
Series A Preferred Units | PAA | |
Partners' Capital and Distributions | |
Schedule of distributions | The following table details distributions to PAA’s Series A preferred unitholders paid during or pertaining to the first three months of 2021 (in millions, except per unit data): Series A Preferred Unitholders Distribution Payment Date Cash Distribution Distribution per Unit May 14, 2021 (1) $ 37 $ 0.525 February 12, 2021 $ 37 $ 0.525 (1) Payable to unitholders of record at the close of business on April 30, 2021 for the period from January 1, 2021 through March 31, 2021. At March 31, 2021, such amount was accrued as distributions payable in “Other current liabilities” on our Condensed Consolidated Balance Sheet. |
Series B Preferred Units | PAA | |
Partners' Capital and Distributions | |
Schedule of distributions | The following table details distributions to be paid to PAA’s Series B preferred unitholders (in millions, except per unit data): Series B Preferred Unitholders Distribution Payment Date Cash Distribution Distribution per Unit May 17, 2021 (1) $ 24.5 $ 30.625 (1) Payable to unitholders of record at the close of business on May 3, 2021 for the period from November 15, 2020 through May 14, 2021. |
Common Units | PAA | |
Partners' Capital and Distributions | |
Schedule of distributions | The following table details distributions to PAA’s common unitholders paid during or pertaining to the first three months of 2021 (in millions, except per unit data): Distributions Cash Distribution Common Unitholders Total Cash Distribution Distribution Payment Date Public AAP May 14, 2021 (1) $ 86 $ 44 $ 130 $ 0.18 February 12, 2021 $ 86 $ 44 $ 130 $ 0.18 (1) Payable to unitholders of record at the close of business on April 30, 2021 for the period from January 1, 2021 through March 31, 2021. |
Derivatives and Risk Manageme_2
Derivatives and Risk Management Activities (Tables) | 3 Months Ended |
Mar. 31, 2021 | |
Derivatives and Risk Management Activities | |
Impact of derivatives recognized in earnings | A summary of the impact of our commodity derivatives recognized in earnings as follows (in millions): Three Months Ended 2021 2020 Supply and Logistics segment revenues $ (314) $ 149 Field operating costs 39 1 Net gain/(loss) from commodity derivative activity $ (275) $ 150 |
Schedule of net broker receivable/(payable) | The following table provides the components of our net broker receivable/(payable) (in millions): March 31, December 31, Initial margin $ 62 $ 91 Variation margin posted/(returned) 259 290 Letters of credit (52) (63) Net broker receivable/(payable) $ 269 $ 318 |
Summary of derivative assets and liabilities on condensed consolidated balance sheets on a gross basis | The following table reflects the Condensed Consolidated Balance Sheet line items that include the fair values of our commodity derivative assets and liabilities and the effect of the collateral netting. Such amounts are presented on a gross basis, before the effects of counterparty netting. However, we have elected to present our commodity derivative assets and liabilities with the same counterparty on a net basis on our Condensed Consolidated Balance Sheet when the legal right of offset exists. Amounts in the table below are presented in millions. March 31, 2021 December 31, 2020 Effect of Collateral Netting Net Carrying Value Presented on the Balance Sheet Effect of Collateral Netting Net Carrying Value Presented on the Balance Sheet Commodity Derivatives Commodity Derivatives Assets Liabilities Assets Liabilities Derivative Assets Other current assets $ 97 $ (261) $ 269 $ 105 $ 71 $ (314) $ 318 $ 75 Other long-term assets, net 4 — — 4 5 — — 5 Derivative Liabilities Other current liabilities 3 (156) — (153) 9 (40) — (31) Other long-term liabilities and deferred credits 1 (58) — (57) — (32) — (32) Total $ 105 $ (475) $ 269 $ (101) $ 85 $ (386) $ 318 $ 17 |
Net unrealized gain/(loss) recognized in AOCI for derivatives | The following table summarizes the net unrealized gain/(loss) recognized in AOCI for derivatives (in millions): Three Months Ended 2021 2020 Interest rate derivatives, net $ 68 $ (79) |
Schedule of derivative financial assets and liabilities accounted for at fair value on a recurring basis, by level within the fair value hierarchy | The following table sets forth by level within the fair value hierarchy our financial assets and liabilities that were accounted for at fair value on a recurring basis (in millions): Fair Value as of March 31, 2021 Fair Value as of December 31, 2020 Recurring Fair Value Measures (1) Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Commodity derivatives $ (241) $ (118) $ (11) $ (370) $ (143) $ (143) $ (15) $ (301) Interest rate derivatives — 114 — 114 — 46 — 46 Foreign currency derivatives — 1 — 1 — 2 — 2 Preferred Distribution Rate Reset Option — — (81) (81) — — (14) (14) Total net derivative asset/(liability) $ (241) $ (3) $ (92) $ (336) $ (143) $ (95) $ (29) $ (267) (1) Derivative assets and liabilities are presented above on a net basis but do not include related cash margin deposits. |
Reconciliation of changes in fair value of derivatives classified as Level 3 | The following table provides a reconciliation of changes in fair value of the beginning and ending balances for our derivatives classified as Level 3 (in millions): Three Months Ended 2021 2020 Beginning Balance $ (29) $ (51) Net losses for the period included in earnings (67) (10) Settlements 4 — Ending Balance $ (92) $ (61) Change in unrealized losses included in earnings relating to Level 3 derivatives still held at the end of the period $ (67) $ (10) |
Commodity Derivatives | |
Derivatives and Risk Management Activities | |
Summary of open derivative positions | The following table summarizes our open derivative positions utilized to hedge the price risk associated with anticipated purchases and sales related to our natural gas processing and NGL fractionation activities as of March 31, 2021: Notional Volume (Short)/Long Remaining Tenor Natural gas purchases 52.5 Bcf March 2022 Propane sales (9.6) MMbls March 2022 Butane sales (3.0) MMbls March 2022 Condensate sales (WTI position) (1.0) MMbls March 2022 Fuel gas requirements (1) 12.5 Bcf December 2022 Power supply requirements (1) 0.8 TWh December 2023 (1) Positions to hedge a portion of our power supply and fuel gas requirements at our Canadian natural gas processing and fractionation plants. |
Interest Rate Derivatives | |
Derivatives and Risk Management Activities | |
Schedule of terms of outstanding interest rate derivatives | The following table summarizes the terms of our outstanding interest rate derivatives as of March 31, 2021 (notional amounts in millions): Hedged Transaction Number and Types of Notional Expected Average Rate Accounting Anticipated interest payments 8 forward starting swaps (30-year) $ 200 6/15/2023 1.38 % Cash flow hedge Anticipated interest payments 8 forward starting swaps (30-year) $ 200 6/14/2024 0.73 % Cash flow hedge |
Foreign Currency Derivatives | |
Derivatives and Risk Management Activities | |
Summary of open derivative positions | The following table summarizes our open forward exchange contracts as of March 31, 2021 (in millions): USD CAD Average Exchange Rate Forward exchange contracts that exchange CAD for USD: 2021 $ 167 $ 210 $1.00 - $1.25 Forward exchange contracts that exchange USD for CAD: 2021 $ 227 $ 285 $1.00 - $1.26 |
Related Party Transactions (Tab
Related Party Transactions (Tables) | 3 Months Ended |
Mar. 31, 2021 | |
Related Party Transactions [Abstract] | |
Schedule of related party transactions | The impact to our Condensed Consolidated Statements of Operations from these transactions is included below (in millions): Three Months Ended 2021 2020 Revenues from related parties (1) $ 7 $ 23 Purchases and related costs from related parties (1) $ 90 $ 129 (1) Crude oil purchases that are part of inventory exchanges under buy/sell transactions are netted with the related sales, with any margin presented in “Purchases and related costs” in our Condensed Consolidated Statements of Operations. Our receivable and payable amounts with these related parties as reflected on our Condensed Consolidated Balance Sheets were as follows (in millions): March 31, December 31, Trade accounts receivable and other receivables, net from related parties (1) $ 25 $ 34 Trade accounts payable to related parties (1) (2) $ 79 $ 88 (1) Includes amounts related to crude oil purchases and sales, transportation and storage services and amounts owed to us or advanced to us related to investment capital projects of equity method investees where we serve as construction manager. (2) We have agreements to store crude oil at facilities and transport crude oil or utilize capacity on pipelines that are owned by equity method investees. A portion of our commitment to transport is supported by crude oil buy/sell or other agreements with third parties with commensurate quantities. |
Operating Segments (Tables)
Operating Segments (Tables) | 3 Months Ended |
Mar. 31, 2021 | |
Segment Reporting [Abstract] | |
Segment financial data | The following tables reflect certain financial data for each segment (in millions): Transportation Facilities Supply and Intersegment Adjustment Total Three Months Ended March 31, 2021 Revenues: External customers (1) $ 234 $ 163 $ 8,083 $ (97) $ 8,383 Intersegment (2) 253 108 — 97 458 Total revenues of reportable segments $ 487 $ 271 $ 8,083 $ — $ 8,841 Equity earnings in unconsolidated entities $ 86 $ 2 $ — $ 88 Segment Adjusted EBITDA $ 388 $ 171 $ (13) $ 546 Maintenance capital $ 26 $ 6 $ 3 $ 35 Three Months Ended March 31, 2020 Revenues: External customers (1) $ 297 $ 175 $ 7,907 $ (110) $ 8,269 Intersegment (2) 282 138 1 110 531 Total revenues of reportable segments $ 579 $ 313 $ 7,908 $ — $ 8,800 Equity earnings in unconsolidated entities $ 108 $ 2 $ — $ 110 Segment Adjusted EBITDA $ 442 $ 210 $ 141 $ 793 Maintenance capital $ 34 $ 14 $ 3 $ 51 (1) Transportation revenues from External customers include tariff revenue from transporting volumes associated with certain inventory exchanges with our customers where our Supply and Logistics segment has transacted the inventory exchange and serves as the shipper on our pipeline systems. See Note 3 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for a discussion of our related accounting policy. We have included an estimate of the revenues from these inventory exchanges in our Transportation segment revenues from External customers presented above and adjusted those revenues out such that Total revenues from External customers reconciles to our Condensed Consolidated Statements of Operations. This presentation is consistent with the information provided to our CODM. (2) Segment revenues include intersegment amounts that are eliminated in Purchases and related costs and Field operating costs in our Condensed Consolidated Statements of Operations. Intersegment activities are conducted at posted tariff rates where applicable, or otherwise at rates similar to those charged to third parties or rates that we believe approximate market at the time the agreement is executed or renegotiated. |
Reconciliation of segment adjusted EBITDA to net income/(loss) attributable to PAGP | The following table reconciles Segment Adjusted EBITDA to Net income/(loss) attributable to PAGP (in millions): Three Months Ended 2021 2020 Segment Adjusted EBITDA $ 546 $ 793 Adjustments: (1) Depreciation and amortization of unconsolidated entities (2) (20) (17) Gains/(losses) from derivative activities and inventory valuation adjustments (3) 198 (30) Long-term inventory costing adjustments (4) 41 (115) Deficiencies under minimum volume commitments, net (5) 32 2 Equity-indexed compensation expense (6) (5) (4) Net gain on foreign currency revaluation (7) 1 13 Significant acquisition-related expenses (8) — (3) Unallocated general and administrative expenses (1) (1) Depreciation and amortization (178) (169) Gains/(losses) on asset sales and asset impairments, net (2) (619) Goodwill impairment losses — (2,515) Gain on/(impairment of) investments in unconsolidated entities, net — (22) Interest expense, net (107) (108) Other expense, net (60) (31) Income/(loss) before tax 445 (2,826) Income tax (expense)/benefit (53) 134 Net income/(loss) 392 (2,692) Net (income)/loss attributable to noncontrolling interests (322) 2,111 Net income/(loss) attributable to PAGP $ 70 $ (581) (1) Represents adjustments utilized by our CODM in the evaluation of segment results. (2) Includes our proportionate share of the depreciation and amortization of unconsolidated entities. (3) We use derivative instruments for risk management purposes and our related processes include specific identification of hedging instruments to an underlying hedged transaction. Although we identify an underlying transaction for each derivative instrument we enter into, there may not be an accounting hedge relationship between the instrument and the underlying transaction. In the course of evaluating our results, we identify differences in the timing of earnings from the derivative instruments and the underlying transactions and exclude the related gains and losses in determining Segment Adjusted EBITDA such that the earnings from the derivative instruments and the underlying transactions impact Segment Adjusted EBITDA in the same period. In addition, we exclude gains and losses on derivatives that are related to investing activities, such as the purchase of linefill. (4) We carry crude oil and NGL inventory that is comprised of minimum working inventory requirements in third-party assets and other working inventory that is needed for our commercial operations. We consider this inventory necessary to conduct our operations and we intend to carry this inventory for the foreseeable future. Therefore, we classify this inventory as long-term on our balance sheet and do not hedge the inventory with derivative instruments (similar to linefill in our own assets). We exclude the impact of changes in the average cost of the long-term inventory (that result from fluctuations in market prices) and write-downs of such inventory that result from price declines from Segment Adjusted EBITDA. (5) We, and certain of our equity method investments, have certain agreements that require counterparties to deliver, transport or throughput a minimum volume over an agreed upon period. Substantially all of such agreements were entered into with counterparties to economically support the return on our capital expenditure necessary to construct the related asset. Some of these agreements include make-up rights if the minimum volume is not met. We record a receivable from the counterparty in the period that services are provided or when the transaction occurs, including amounts for deficiency obligations from counterparties associated with minimum volume commitments. If a counterparty has a make-up right associated with a deficiency, we defer the revenue attributable to the counterparty’s make-up right and subsequently recognize the revenue at the earlier of when the deficiency volume is delivered or shipped, when the make-up right expires or when it is determined that the counterparty’s ability to utilize the make-up right is remote. We include the impact of amounts billed to counterparties for their deficiency obligation, net of applicable amounts subsequently recognized into revenue, as a selected item impacting comparability. Our CODM views the inclusion of the contractually committed revenues associated with that period as meaningful to Segment Adjusted EBITDA as the related asset has been constructed, is standing ready to provide the committed service and the fixed operating costs are included in the current period results. (6) Our total equity-indexed compensation expense includes expense associated with awards that will be settled in PAA common units and awards that will be settled in cash. The awards that will be settled in PAA common units are included in PAA’s diluted net income per unit calculation when the applicable performance criteria have been met. We exclude compensation expense associated with these awards in determining Segment Adjusted EBITDA as the dilutive impact of the outstanding awards is included in PAA’s diluted net income per unit calculation, as applicable. The portion of compensation expense associated with awards that will settle in cash is not excluded in determining Segment Adjusted EBITDA. See Note 18 to our Consolidated Financial Statements included in Part IV of our 2020 Annual Report on Form 10-K for a discussion regarding our equity-indexed compensation plans. (7) During the periods presented, there were fluctuations in the value of CAD to USD, resulting in the realization of foreign exchange gains and losses on the settlement of foreign currency transactions as well as the revaluation of monetary assets and liabilities denominated in a foreign currency. These gains and losses are not integral to our core operating performance and were therefore excluded in determining Segment Adjusted EBITDA. See Note 8 for discussion regarding our currency exchange rate risk hedging activities. |
Organization and Basis of Con_2
Organization and Basis of Consolidation and Presentation - Additional Information (Details) shares in Millions, $ in Millions | 3 Months Ended | |
Mar. 31, 2021USD ($)segmentshares | Dec. 31, 2020USD ($) | |
Organization and basis of presentation | ||
Operating segments number | segment | 3 | |
Deferred tax asset | $ | $ 1,408 | $ 1,444 |
PAA | AAP | ||
Organization and basis of presentation | ||
Ownership interest | 31.00% | |
Ownership interest (in units) | 245.5 | |
GP LLC | ||
Organization and basis of presentation | ||
Ownership interest | 100.00% | |
AAP | ||
Organization and basis of presentation | ||
Ownership interest | 79.00% | |
Ownership interest (in units) | 193.1 | |
AAP | GP LLC | ||
Organization and basis of presentation | ||
Ownership interest (in units) | 1 | |
Consolidated Entity Excluding VIE | ||
Organization and basis of presentation | ||
Deferred tax asset | $ | $ 1,408 | $ 1,444 |
Summary of Significant Accoun_4
Summary of Significant Accounting Policies - Cash and Restricted Cash (Details) - USD ($) $ in Millions | Mar. 31, 2021 | Dec. 31, 2020 | Mar. 31, 2020 | Dec. 31, 2019 |
Accounting Policies [Abstract] | ||||
Cash and cash equivalents | $ 32 | $ 25 | ||
Restricted cash | 26 | 38 | ||
Total cash and cash equivalents and restricted cash | $ 58 | $ 63 | $ 162 | $ 84 |
Summary of Significant Accoun_5
Summary of Significant Accounting Policies - Additional Information (Details) - USD ($) $ / shares in Units, $ in Millions | 3 Months Ended | 12 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | Dec. 31, 2020 | |
Property, Plant and Equipment [Line Items] | |||
Depreciation and amortization | $ 178 | $ 169 | |
Service Life | |||
Property, Plant and Equipment [Line Items] | |||
Depreciation and amortization | $ 18 | ||
Class A Shares | |||
Property, Plant and Equipment [Line Items] | |||
Basic and diluted net income/(loss) per Class A share (in dollars per share) | $ 0.36 | $ (3.18) | |
Class A Shares | Service Life | |||
Property, Plant and Equipment [Line Items] | |||
Basic and diluted net income/(loss) per Class A share (in dollars per share) | $ (0.02) | ||
Pipeline and related facilities and Storage, terminal and rail facilities | Minimum | |||
Property, Plant and Equipment [Line Items] | |||
Property and equipment, useful life | 10 years | ||
Pipeline and related facilities and Storage, terminal and rail facilities | Minimum | Service Life | |||
Property, Plant and Equipment [Line Items] | |||
Property and equipment, useful life | 10 years | ||
Pipeline and related facilities and Storage, terminal and rail facilities | Maximum | |||
Property, Plant and Equipment [Line Items] | |||
Property and equipment, useful life | 70 years | ||
Pipeline and related facilities and Storage, terminal and rail facilities | Maximum | Service Life | |||
Property, Plant and Equipment [Line Items] | |||
Property and equipment, useful life | 50 years |
Revenues and Accounts Receiva_3
Revenues and Accounts Receivable - Disaggregation of Revenue (Details) - Operating Segments - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | |
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | $ 9,095 | $ 8,628 |
Supply and Logistics | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 8,395 | 7,750 |
Supply and Logistics | Crude oil transactions | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 7,711 | 7,322 |
Supply and Logistics | NGL and other transactions | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 684 | 428 |
Transportation | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 446 | 573 |
Transportation | Total tariff activities | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 424 | 538 |
Transportation | Crude oil pipelines | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 397 | 512 |
Transportation | NGL pipelines | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 27 | 26 |
Transportation | Trucking | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 22 | 35 |
Facilities | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 254 | 305 |
Facilities | Crude oil, NGL and other terminalling and storage | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 170 | 182 |
Facilities | NGL and natural gas processing and fractionation | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 73 | 109 |
Facilities | Rail load / unload | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | $ 11 | $ 14 |
Revenues and Accounts Receiva_4
Revenues and Accounts Receivable - Segment Revenue (Details) - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | |
Disaggregation of Revenue [Line Items] | ||
Total revenues | $ 8,383 | $ 8,269 |
Transportation | ||
Disaggregation of Revenue [Line Items] | ||
Total revenues | 137 | 187 |
Facilities | ||
Disaggregation of Revenue [Line Items] | ||
Total revenues | 163 | 175 |
Supply and Logistics | ||
Disaggregation of Revenue [Line Items] | ||
Total revenues | 8,083 | 7,907 |
Operating Segments | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 9,095 | 8,628 |
Total revenues | 8,841 | 8,800 |
Operating Segments | Transportation | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 446 | 573 |
Total revenues | 487 | 579 |
Operating Segments | Facilities | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 254 | 305 |
Total revenues | 271 | 313 |
Operating Segments | Supply and Logistics | ||
Disaggregation of Revenue [Line Items] | ||
Revenues from contracts with customers | 8,395 | 7,750 |
Total revenues | 8,083 | 7,908 |
Intersegment | ||
Disaggregation of Revenue [Line Items] | ||
Total revenues | (458) | (531) |
Intersegment | Transportation | ||
Disaggregation of Revenue [Line Items] | ||
Total revenues | (253) | (282) |
Intersegment | Facilities | ||
Disaggregation of Revenue [Line Items] | ||
Total revenues | (108) | (138) |
Intersegment | Supply and Logistics | ||
Disaggregation of Revenue [Line Items] | ||
Total revenues | (1) | |
Other | Operating Segments | ||
Disaggregation of Revenue [Line Items] | ||
Total revenues | (254) | 172 |
Other | Operating Segments | Transportation | ||
Disaggregation of Revenue [Line Items] | ||
Total revenues | 41 | 6 |
Other | Operating Segments | Facilities | ||
Disaggregation of Revenue [Line Items] | ||
Total revenues | 17 | 8 |
Other | Operating Segments | Supply and Logistics | ||
Disaggregation of Revenue [Line Items] | ||
Total revenues | $ (312) | $ 158 |
Revenues and Accounts Receiva_5
Revenues and Accounts Receivable - Counterparty Deficiencies (Details) - USD ($) $ in Millions | Mar. 31, 2021 | Dec. 31, 2020 |
Minimum Volume Commitments [Line Items] | ||
Counterparty deficiencies billed and collected | $ 494 | $ 501 |
Minimum Volume Commitments | ||
Minimum Volume Commitments [Line Items] | ||
Counterparty deficiencies billed and collected | 47 | 73 |
Counterparty deficiencies unbilled | 24 | 4 |
Counterparty deficiencies | $ 71 | $ 77 |
Revenues and Accounts Receiva_6
Revenues and Accounts Receivable - Contract Balances (Details) - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2021 | Dec. 31, 2020 | |
Change in Contract with Customer, Liability [Roll Forward] | ||
Beginning balance | $ 501 | |
Amounts recognized as revenue | (380) | |
Additions | 373 | |
Ending balance | 494 | $ 501 |
Crude Oil Sales Agreements Entered Into In Conjunction With Storage Arrangements And Future Inventory Exchanges Member | ||
Change in Contract with Customer, Liability [Roll Forward] | ||
Amounts recognized as revenue | $ (361) | |
Additions | $ 346 |
Revenues and Accounts Receiva_7
Revenues and Accounts Receivable - Performance Obligations (Details) $ in Millions | Mar. 31, 2021USD ($) |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2021-04-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 410 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | 473 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | 391 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | 325 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2025-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | 242 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2026-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | 788 |
Pipeline revenues supported by minimum volume commitments and capacity agreements | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2021-04-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 135 |
Remaining performance obligation, expected timing of satisfaction, period | 1 year |
Pipeline revenues supported by minimum volume commitments and capacity agreements | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 171 |
Remaining performance obligation, expected timing of satisfaction, period | 1 year |
Pipeline revenues supported by minimum volume commitments and capacity agreements | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 171 |
Remaining performance obligation, expected timing of satisfaction, period | 1 year |
Pipeline revenues supported by minimum volume commitments and capacity agreements | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 146 |
Remaining performance obligation, expected timing of satisfaction, period | 1 year |
Pipeline revenues supported by minimum volume commitments and capacity agreements | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2025-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 126 |
Remaining performance obligation, expected timing of satisfaction, period | 1 year |
Pipeline revenues supported by minimum volume commitments and capacity agreements | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2026-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 456 |
Remaining performance obligation, expected timing of satisfaction, period | |
Storage, terminalling and throughput agreement revenues | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2021-04-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 275 |
Remaining performance obligation, expected timing of satisfaction, period | 1 year |
Storage, terminalling and throughput agreement revenues | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 302 |
Remaining performance obligation, expected timing of satisfaction, period | 1 year |
Storage, terminalling and throughput agreement revenues | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 220 |
Remaining performance obligation, expected timing of satisfaction, period | 1 year |
Storage, terminalling and throughput agreement revenues | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 179 |
Remaining performance obligation, expected timing of satisfaction, period | 1 year |
Storage, terminalling and throughput agreement revenues | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2025-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 116 |
Remaining performance obligation, expected timing of satisfaction, period | 1 year |
Storage, terminalling and throughput agreement revenues | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2026-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction | |
Remaining performance obligation | $ 332 |
Remaining performance obligation, expected timing of satisfaction, period |
Revenues and Accounts Receiva_8
Revenues and Accounts Receivable - Narrative (Details) | 3 Months Ended | 12 Months Ended |
Mar. 31, 2021 | Dec. 31, 2019 | |
Revenue from Contract with Customer [Abstract] | ||
General payment terms | 30 days | |
Substantially all trade accounts receivable, net, maximum age of balances past their invoice date | 30 days | 30 days |
Revenues and Accounts Receiva_9
Revenues and Accounts Receivable - Trade Accounts Receivable and Other Receivables (Details) - USD ($) $ in Millions | Mar. 31, 2021 | Dec. 31, 2020 |
Revenue from Contract with Customer [Abstract] | ||
Trade accounts receivable arising from revenues from contracts with customers | $ 3,140 | $ 2,317 |
Other trade accounts receivables and other receivables | 3,582 | 2,818 |
Impact due to contractual rights of offset with counterparties | (3,321) | (2,582) |
Trade accounts receivable and other receivables, net | $ 3,401 | $ 2,553 |
Net Income_(Loss) Per Class A_2
Net Income/(Loss) Per Class A Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | 3 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | |
Basic and Diluted Net Income/(Loss) per Class A Share | ||
Net income/(loss) attributable to PAGP | $ 70 | $ (581) |
AAP Units | ||
Net Income Per Class A Share | ||
Antidilutive securities excluded from computation of earnings per share (per share) | 51 | 63 |
AAP Management Units | ||
Net Income Per Class A Share | ||
Antidilutive securities excluded from computation of earnings per share (per share) | 1 | 1 |
Class A Shares | ||
Basic and Diluted Net Income/(Loss) per Class A Share | ||
Basic and diluted weighted average Class A shares outstanding (in shares) | 194 | 183 |
Basic and diluted net income/(loss) per Class A share (in dollars per share) | $ 0.36 | $ (3.18) |
Maximum | ||
Net Income Per Class A Share | ||
Dilutive LTIP awards (shares) | 0.1 |
Inventory, Linefill and Base _3
Inventory, Linefill and Base Gas and Long-term Inventory (Details) bbl in Thousands, Mcf in Thousands, $ in Millions | Mar. 31, 2021USD ($)$ / bbl$ / McfMcfbbl | Dec. 31, 2020USD ($)$ / bbl$ / McfbblMcf |
Inventory by category | ||
Inventory | $ 484 | $ 647 |
Linefill and base gas | 983 | 982 |
Long-term inventory | 178 | 130 |
Total | $ 1,645 | $ 1,759 |
Crude oil | ||
Inventory by category | ||
Inventory, Volumes (in barrels) | bbl | 8,896 | 13,450 |
Linefill and base gas, Volumes (in barrels or in Mcf) | bbl | 14,653 | 14,669 |
Long-term inventory, Volumes (in barrels) | bbl | 2,669 | 2,499 |
Inventory | $ 373 | $ 441 |
Linefill and base gas | 828 | 828 |
Long-term inventory | $ 154 | $ 111 |
Inventory (Price/Unit of measure) | $ / bbl | 41.93 | 32.79 |
Linefill and base gas (Price/Unit of measure) | $ / bbl | 56.51 | 56.45 |
Long-term inventory (Price/Unit of measure) | $ / bbl | 57.70 | 44.42 |
NGL | ||
Inventory by category | ||
Inventory, Volumes (in barrels) | bbl | 4,872 | 12,302 |
Linefill and base gas, Volumes (in barrels or in Mcf) | bbl | 1,650 | 1,640 |
Long-term inventory, Volumes (in barrels) | bbl | 1,105 | 1,185 |
Inventory | $ 105 | $ 199 |
Linefill and base gas | 45 | 44 |
Long-term inventory | $ 24 | $ 19 |
Inventory (Price/Unit of measure) | $ / bbl | 21.55 | 16.18 |
Linefill and base gas (Price/Unit of measure) | $ / bbl | 27.27 | 26.83 |
Long-term inventory (Price/Unit of measure) | $ / bbl | 21.72 | 16.03 |
Natural gas | ||
Inventory by category | ||
Linefill and base gas, Volumes (in barrels or in Mcf) | Mcf | 25,576 | 25,576 |
Linefill and base gas | $ 110 | $ 110 |
Linefill and base gas (Price/Unit of measure) | $ / Mcf | 4.30 | 4.30 |
Other | ||
Inventory by category | ||
Inventory | $ 6 | $ 7 |
Debt - Components (Details)
Debt - Components (Details) - USD ($) $ in Millions | Mar. 31, 2021 | Dec. 31, 2020 |
Short-term debt: | ||
Total short-term debt | $ 254 | $ 831 |
Long-term debt: | ||
Senior notes, net | 9,073 | 9,071 |
Other long-term debt, net | 265 | 311 |
Total long-term debt | 9,338 | 9,382 |
Total debt | 9,592 | 10,213 |
Senior notes | ||
Long-term debt: | ||
Senior notes, net | 9,073 | 9,071 |
Unamortized discounts and debt issuance costs | 60 | 62 |
Debt instrument face value | 9,100 | 9,100 |
Other | ||
Long-term debt: | ||
Other long-term debt, net | 66 | 112 |
Level 2 | Senior notes | ||
Long-term debt: | ||
Debt instrument fair value | 9,500 | 9,900 |
Other | ||
Short-term debt: | ||
Total short-term debt | 117 | 117 |
Commercial Paper | Line of Credit | ||
Short-term debt: | ||
Short-term debt | $ 137 | $ 547 |
Weighted average interest rate, short-term | 0.60% | 0.70% |
Senior Secured Hedged Inventory Facility | Line of Credit | ||
Short-term debt: | ||
Short-term debt | $ 167 | |
Weighted average interest rate, short-term | 1.20% | |
GO Zone term loans | Term loan | ||
Long-term debt: | ||
Other long-term debt, net | $ 199 | $ 199 |
Debt issuance costs | $ 1 | $ 1 |
Weighted average interest rate, long-term | 1.30% | 1.30% |
Debt - Letters of Credit, Borro
Debt - Letters of Credit, Borrowings and Repayments (Details) - USD ($) $ in Millions | 3 Months Ended | ||
Mar. 31, 2021 | Mar. 31, 2020 | Dec. 31, 2020 | |
Debt | |||
Outstanding letters of credit | $ 130 | $ 129 | |
Credit facilities and PAA commercial paper program | |||
Debt | |||
Total borrowings | 14,200 | $ 9,600 | |
Total repayments | $ 14,800 | $ 9,600 |
Partners' Capital and Distrib_3
Partners' Capital and Distributions - Exchange Rights and Shares Activity (Details) - shares | 3 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | |
Class A Shares | ||
Activity for Class A shares, Class B shares and Class C shares | ||
Balance, beginning of period (shares) | 194,051,436 | 182,138,592 |
Exchange Right exercises (shares) | 46,879 | 2,101,487 |
Balance, end of period (shares) | 194,098,315 | 184,240,079 |
Class B Shares | ||
Activity for Class A shares, Class B shares and Class C shares | ||
Balance, beginning of period (shares) | 50,640,192 | 65,785,702 |
Conversion of AAP Management Units (shares) | 414,608 | 559,768 |
Exchange Right exercises (shares) | (46,879) | (2,101,487) |
Redemption Right exercises (shares) | (229,931) | (1,206,599) |
Balance, end of period (shares) | 50,777,990 | 63,037,384 |
Class C Shares | ||
Activity for Class A shares, Class B shares and Class C shares | ||
Balance, beginning of period (shares) | 547,717,762 | 549,538,139 |
Redemption Right exercises (shares) | 229,931 | 1,206,599 |
Repurchase of common units by a subsidiary under Common Equity Repurchase Program (shares) | (350,000) | |
Other (shares) | 25,431 | 24,431 |
Balance, end of period (shares) | 547,623,124 | 550,769,169 |
Partners' Capital and Distrib_4
Partners' Capital and Distributions - Distributions, Class A (Details) - Cash Distribution - Class A Shares - USD ($) $ / shares in Units, $ in Millions | May 14, 2021 | Feb. 12, 2021 |
Partners' Capital and Distributions | ||
Distributions to Class A shareholders | $ 35 | |
Distribution per Class A share, paid (usd per share) | $ 0.18 | |
Forecast | ||
Partners' Capital and Distributions | ||
Distributions to Class A shareholders | $ 35 | |
Distribution per Class A share, paid (usd per share) | $ 0.18 |
Partners' Capital and Distrib_5
Partners' Capital and Distributions - Noncontrolling Interests in Subsidiaries (Details) - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | |
Partners' Capital and Distributions | ||
Distributions | $ 185 | $ 311 |
Noncontrolling Interests | ||
Partners' Capital and Distributions | ||
Distributions | $ 150 | $ 245 |
AAP | ||
Partners' Capital and Distributions | ||
Noncontrolling interests in subsidiaries (percent) | 21.00% | |
Red River LLC | ||
Partners' Capital and Distributions | ||
Noncontrolling interests in subsidiaries (percent) | 33.00% | |
Common Units and Series A Preferred Units | PAA | ||
Partners' Capital and Distributions | ||
Noncontrolling interests in subsidiaries (percent) | 69.00% | |
Series B Preferred Units | PAA | ||
Partners' Capital and Distributions | ||
Noncontrolling interests in subsidiaries (percent) | 100.00% | |
Red River LLC | Noncontrolling Interests | ||
Partners' Capital and Distributions | ||
Distributions | $ 6 |
Partners' Capital and Distrib_6
Partners' Capital and Distributions - Subsidiary Distributions (Details) - USD ($) $ / shares in Units, $ in Millions | May 17, 2021 | May 14, 2021 | Feb. 12, 2021 | Mar. 31, 2021 | Mar. 31, 2020 |
Partners' Capital and Distributions | |||||
Total distributions paid | $ 185 | $ 311 | |||
PAA | Series A Preferred Units | Cash Distribution | |||||
Partners' Capital and Distributions | |||||
Preferred unit distribution amount | $ 37 | ||||
Preferred unit distribution amount (in dollars per unit) | $ 0.525 | ||||
PAA | Series A Preferred Units | Cash Distribution | Forecast | |||||
Partners' Capital and Distributions | |||||
Preferred unit distribution amount | $ 37 | ||||
Preferred unit distribution amount (in dollars per unit) | $ 0.525 | ||||
PAA | Series B Preferred Units | Cash Distribution | Forecast | |||||
Partners' Capital and Distributions | |||||
Preferred unit distribution amount | $ 24.5 | ||||
Preferred unit distribution amount (in dollars per unit) | $ 30.625 | ||||
PAA | Common Units | Cash Distribution | |||||
Partners' Capital and Distributions | |||||
Total distributions paid | $ 130 | ||||
Distributions per common unit, paid (usd per unit) | $ 0.18 | ||||
PAA | Common Units | Cash Distribution | Forecast | |||||
Partners' Capital and Distributions | |||||
Total distributions paid | $ 130 | ||||
Distributions per common unit, paid (usd per unit) | $ 0.18 | ||||
AAP | Cash Distribution | |||||
Partners' Capital and Distributions | |||||
Distributions to noncontrolling interests | $ 9 | ||||
Distributions to PAGP | 35 | ||||
Total distributions paid | 44 | ||||
AAP | Cash Distribution | Forecast | |||||
Partners' Capital and Distributions | |||||
Distributions to noncontrolling interests | $ 9 | ||||
Distributions to PAGP | 35 | ||||
Total distributions paid | 44 | ||||
Public | PAA | Common Units | Cash Distribution | |||||
Partners' Capital and Distributions | |||||
Distributions to common unitholders | 86 | ||||
Public | PAA | Common Units | Cash Distribution | Forecast | |||||
Partners' Capital and Distributions | |||||
Distributions to common unitholders | 86 | ||||
AAP | PAA | Common Units | Cash Distribution | |||||
Partners' Capital and Distributions | |||||
Distributions to common unitholders | $ 44 | ||||
AAP | PAA | Common Units | Cash Distribution | Forecast | |||||
Partners' Capital and Distributions | |||||
Distributions to common unitholders | $ 44 | ||||
Other current liabilities | PAA | Series B Preferred Units | |||||
Partners' Capital and Distributions | |||||
Amount accrued to distributions payable | 18 | ||||
Noncontrolling Interests | |||||
Partners' Capital and Distributions | |||||
Total distributions paid | 150 | $ 245 | |||
Noncontrolling Interests | Red River LLC | |||||
Partners' Capital and Distributions | |||||
Total distributions paid | $ 6 |
Derivatives and Risk Manageme_3
Derivatives and Risk Management Activities - Commodity Price Risk Hedging (Details) bbl in Millions | 3 Months Ended |
Mar. 31, 2021TWhbblMMBblsBcf | |
Net long position associated with crude oil purchases | |
Commodity Price Risk Hedging: | |
Derivative position notional amount (in barrels, MMbls or Bcf) | 9.3 |
Net short time spread position hedging anticipated crude oil lease gathering purchases | |
Commodity Price Risk Hedging: | |
Derivative position notional amount (in barrels, MMbls or Bcf) | 6.5 |
Net crude oil basis spread position | |
Commodity Price Risk Hedging: | |
Derivative position notional amount (in barrels, MMbls or Bcf) | 1.1 |
Net short position related to anticipated net sales of crude oil and NGL inventory | |
Commodity Price Risk Hedging: | |
Derivative position notional amount (in barrels, MMbls or Bcf) | 20.1 |
Long natural gas position for natural gas purchases for processing and operational needs | |
Commodity Price Risk Hedging: | |
Derivative position notional amount (in barrels, MMbls or Bcf) | Bcf | 52.5 |
Short propane position related to subsequent sale of products | |
Commodity Price Risk Hedging: | |
Derivative position notional amount (in barrels, MMbls or Bcf) | MMBbls | 9.6 |
Short butane position related to subsequent sale of products | |
Commodity Price Risk Hedging: | |
Derivative position notional amount (in barrels, MMbls or Bcf) | MMBbls | 3 |
Short condensate WTI position related to subsequent sale of products | |
Commodity Price Risk Hedging: | |
Derivative position notional amount (in barrels, MMbls or Bcf) | MMBbls | 1 |
Long fuel gas position for fuel gas requirements | |
Commodity Price Risk Hedging: | |
Derivative position notional amount (in barrels, MMbls or Bcf) | Bcf | 12.5 |
Long power position for power supply requirements | |
Commodity Price Risk Hedging: | |
Derivative position notional amount (in Terawatt hours) | TWh | 0.8 |
Derivatives and Risk Manageme_4
Derivatives and Risk Management Activities - Financial Impact (Details) - Derivatives Not Designated as a Hedge - Commodity Derivatives - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | |
Impact of derivative activities recognized in earnings | ||
Total gain/(loss) on derivatives recognized in net income | $ (275) | $ 150 |
Supply and Logistics segment revenues | ||
Impact of derivative activities recognized in earnings | ||
Total gain/(loss) on derivatives recognized in net income | (314) | 149 |
Field operating costs | ||
Impact of derivative activities recognized in earnings | ||
Total gain/(loss) on derivatives recognized in net income | $ 39 | $ 1 |
Derivatives and Risk Manageme_5
Derivatives and Risk Management Activities - Broker Receivable/Payable (Details) - USD ($) $ in Millions | Mar. 31, 2021 | Dec. 31, 2020 |
Offsetting Assets, Liabilities [Line Items] | ||
Initial margin | $ 62 | $ 91 |
Variation margin posted/(returned) | 259 | 290 |
Letters of credit | (130) | (129) |
Net broker receivable/(payable) | 269 | 318 |
Exchange traded | ||
Offsetting Assets, Liabilities [Line Items] | ||
Letters of credit | $ (52) | $ (63) |
Derivatives and Risk Manageme_6
Derivatives and Risk Management Activities - Offsetting Asset and Liabilities (Details) - USD ($) $ in Millions | Mar. 31, 2021 | Dec. 31, 2020 |
Derivative Asset Positions | ||
Effect of Collateral Netting | $ 269 | $ 318 |
Commodity Derivatives | ||
Derivative Asset Positions | ||
Effect of Collateral Netting | 269 | 318 |
Derivative Liability Positions | ||
Gross Position - Asset | 105 | 85 |
Gross Position - Liability | (475) | (386) |
Net Carrying Value Presented on the Balance Sheet, Total | (101) | 17 |
Other current assets | Commodity Derivatives | ||
Derivative Asset Positions | ||
Gross Position - Asset | 97 | 71 |
Gross Position - Liability | (261) | (314) |
Effect of Collateral Netting | 269 | 318 |
Net Carrying Value Presented on the Balance Sheet | 105 | 75 |
Other long-term assets, net | Commodity Derivatives | ||
Derivative Asset Positions | ||
Gross Position - Asset | 4 | 5 |
Gross Position - Liability | 0 | 0 |
Net Carrying Value Presented on the Balance Sheet | 4 | 5 |
Other current liabilities | Commodity Derivatives | ||
Derivative Liability Positions | ||
Gross Position - Asset | 3 | 9 |
Gross Position - Liability | (156) | (40) |
Net Carrying Value Presented on the Balance Sheet | (153) | (31) |
Other long-term liabilities and deferred credits | Commodity Derivatives | ||
Derivative Liability Positions | ||
Gross Position - Asset | 1 | |
Gross Position - Liability | (58) | (32) |
Net Carrying Value Presented on the Balance Sheet | $ (57) | $ (32) |
Derivatives and Risk Manageme_7
Derivatives and Risk Management Activities - Interest Rate Risk Hedging (Details) - Cash flow hedge $ in Millions | 3 Months Ended |
Mar. 31, 2021USD ($)contract | |
8 forward starting interest rate swaps (30-year), 1.38% | |
Interest Rate Risk Hedging | |
Number of interest rate derivatives | contract | 8 |
Term of derivative contract | 30 years |
Notional amount of derivatives | $ | $ 200 |
Average rate locked (percent) | 1.38% |
8 forward starting interest rate swaps (30-year), 0.73% | |
Interest Rate Risk Hedging | |
Number of interest rate derivatives | contract | 8 |
Term of derivative contract | 30 years |
Notional amount of derivatives | $ | $ 200 |
Average rate locked (percent) | 0.73% |
Derivatives and Risk Manageme_8
Derivatives and Risk Management Activities - Net Unrealized Gain/(Loss) Recognized in AOCI (Details) - USD ($) $ in Millions | 3 Months Ended | ||
Mar. 31, 2021 | Mar. 31, 2020 | Dec. 31, 2020 | |
Derivative assets and liabilities | |||
Net loss reclassified to earnings | $ 3 | $ 2 | |
Net loss expected to be reclassified to earnings in the next twelve months | 13 | ||
Other long-term assets, net | |||
Derivative assets and liabilities | |||
Interest rate fair value hedge liability at fair value | 114 | $ 46 | |
AOCI cash flow hedge | |||
Derivative assets and liabilities | |||
Net loss deferred in AOCI | 187 | ||
Interest Rate Derivatives | |||
Derivative assets and liabilities | |||
Net unrealized gain/(loss) recognized in AOCI | $ 68 | $ (79) |
Derivatives and Risk Manageme_9
Derivatives and Risk Management Activities - Currency Exchange Rate Risk Hedging (Details) $ in Millions, $ in Millions | 3 Months Ended | |||
Mar. 31, 2021USD ($)$ / $ | Mar. 31, 2020USD ($) | Mar. 31, 2021CAD ($)$ / $ | Dec. 31, 2020USD ($) | |
Foreign Currency Derivatives | Derivatives Not Designated as a Hedge | Supply and Logistics segment revenues | ||||
Currency Exchange Rate Risk Hedging: | ||||
Gain/(loss) recognized in earnings | $ | $ 1 | $ (6) | ||
Forward exchange contracts that exchange CAD For USD maturing in 2021 | ||||
Currency Exchange Rate Risk Hedging: | ||||
Notional amount of derivatives | $ 167 | $ 210 | ||
Forward exchange contracts that exchange CAD For USD maturing in 2021 | Minimum | ||||
Currency Exchange Rate Risk Hedging: | ||||
Average exchange rate (cad per usd) | 1 | 1 | ||
Forward exchange contracts that exchange CAD For USD maturing in 2021 | Maximum | ||||
Currency Exchange Rate Risk Hedging: | ||||
Average exchange rate (cad per usd) | 1.25 | 1.25 | ||
Forward exchange contracts that exchange USD for CAD maturing in 2021 | ||||
Currency Exchange Rate Risk Hedging: | ||||
Notional amount of derivatives | $ 227 | $ 285 | ||
Forward exchange contracts that exchange USD for CAD maturing in 2021 | Minimum | ||||
Currency Exchange Rate Risk Hedging: | ||||
Average exchange rate (cad per usd) | 1 | 1 | ||
Forward exchange contracts that exchange USD for CAD maturing in 2021 | Maximum | ||||
Currency Exchange Rate Risk Hedging: | ||||
Average exchange rate (cad per usd) | 1.26 | 1.26 | ||
Interest Rate Derivatives | Derivatives in Hedging Relationships | Other current assets | ||||
Currency Exchange Rate Risk Hedging: | ||||
Derivative asset | $ | $ 1 | $ 2 |
Derivatives and Risk Managem_10
Derivatives and Risk Management Activities - Preferred Distribution Rate (Details) - USD ($) $ in Millions | 3 Months Ended | ||
Mar. 31, 2021 | Mar. 31, 2020 | Dec. 31, 2020 | |
Derivatives and Risk Management Activities | |||
Gain/(loss) recognized | $ (67) | $ 26 | |
Preferred Distribution Rate Reset Option | Derivatives Not Designated as a Hedge | Other long-term liabilities and deferred credits | |||
Derivatives and Risk Management Activities | |||
Derivative liability | 81 | $ 14 | |
Preferred Distribution Rate Reset Option | Derivatives Not Designated as a Hedge | Other expense, net | |||
Derivatives and Risk Management Activities | |||
Gain/(loss) recognized | $ 67 | $ 26 |
Derivatives and Risk Managem_11
Derivatives and Risk Management Activities - Fair Value (Details) - USD ($) $ in Millions | 3 Months Ended | ||
Mar. 31, 2021 | Mar. 31, 2020 | Dec. 31, 2020 | |
Level 3 | |||
Rollforward of Level 3 Net Asset/(Liability) | |||
Beginning Balance | $ (29) | $ (51) | |
Net losses for the period included in earnings | (67) | (10) | |
Settlements | 4 | ||
Ending Balance | (92) | (61) | |
Change in unrealized losses included in earnings relating to Level 3 derivatives still held at the end of the period | (67) | $ (10) | |
Recurring Fair Value Measures | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | (336) | $ (267) | |
Recurring Fair Value Measures | Commodity Derivatives | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | (370) | (301) | |
Recurring Fair Value Measures | Interest Rate Derivatives | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | 114 | 46 | |
Recurring Fair Value Measures | Foreign Currency Derivatives | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | 1 | 2 | |
Recurring Fair Value Measures | Preferred Distribution Rate Reset Option | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | (81) | (14) | |
Recurring Fair Value Measures | Level 1 | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | (241) | (143) | |
Recurring Fair Value Measures | Level 1 | Commodity Derivatives | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | (241) | (143) | |
Recurring Fair Value Measures | Level 1 | Interest Rate Derivatives | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | 0 | 0 | |
Recurring Fair Value Measures | Level 1 | Foreign Currency Derivatives | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | 0 | 0 | |
Recurring Fair Value Measures | Level 1 | Preferred Distribution Rate Reset Option | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | 0 | 0 | |
Recurring Fair Value Measures | Level 2 | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | (3) | (95) | |
Recurring Fair Value Measures | Level 2 | Commodity Derivatives | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | (118) | (143) | |
Recurring Fair Value Measures | Level 2 | Interest Rate Derivatives | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | 114 | 46 | |
Recurring Fair Value Measures | Level 2 | Foreign Currency Derivatives | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | 1 | 2 | |
Recurring Fair Value Measures | Level 2 | Preferred Distribution Rate Reset Option | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | 0 | 0 | |
Recurring Fair Value Measures | Level 3 | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | (92) | (29) | |
Recurring Fair Value Measures | Level 3 | Commodity Derivatives | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | (11) | (15) | |
Recurring Fair Value Measures | Level 3 | Interest Rate Derivatives | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | 0 | 0 | |
Recurring Fair Value Measures | Level 3 | Foreign Currency Derivatives | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | 0 | 0 | |
Recurring Fair Value Measures | Level 3 | Preferred Distribution Rate Reset Option | |||
Recurring Fair Value Measurements | |||
Total net derivative asset/(liability) | $ (81) | $ (14) |
Related Party Transactions (Det
Related Party Transactions (Details) - USD ($) $ in Millions | 3 Months Ended | ||
Mar. 31, 2021 | Mar. 31, 2020 | Dec. 31, 2020 | |
Related Party Transactions [Abstract] | |||
Revenues from related parties | $ 7 | $ 23 | |
Purchases and related costs from related parties | 90 | $ 129 | |
Trade accounts receivable and other receivables, net from related parties | 25 | $ 34 | |
Trade accounts payable to related parties | $ 79 | $ 88 |
Commitments and Contingencies -
Commitments and Contingencies - Legal, Environmental or Regulatory (Details) $ in Thousands | 1 Months Ended | 6 Months Ended | 71 Months Ended | |||
May 31, 2015bbl | Mar. 31, 2021USD ($) | Mar. 31, 2021USD ($)lawsuit | Dec. 31, 2020USD ($) | Apr. 25, 2019USD ($) | Sep. 07, 2018count | |
Legal, Environmental or Regulatory Matters | ||||||
Estimated undiscounted reserve for environmental liabilities | $ 160,000 | $ 160,000 | $ 141,000 | |||
Estimated undiscounted reserve for environmental liabilities, short-term | 114,000 | 114,000 | 94,000 | |||
Amounts probable of recovery under insurance and from third parties under indemnification agreements | 114,000 | 114,000 | 97,000 | |||
Other long-term liabilities and deferred credits | ||||||
Legal, Environmental or Regulatory Matters | ||||||
Estimated undiscounted reserve for environmental liabilities, long-term | 46,000 | 46,000 | 47,000 | |||
Trade accounts receivable and other receivables, net | ||||||
Legal, Environmental or Regulatory Matters | ||||||
Amounts probable of recovery under insurance and from third parties under indemnification agreements | 113,000 | 113,000 | 96,000 | |||
Other long-term assets, net | ||||||
Legal, Environmental or Regulatory Matters | ||||||
Amounts probable of recovery under insurance and from third parties under indemnification agreements | 1,000 | 1,000 | $ 1,000 | |||
Line 901 Incident | ||||||
Legal, Environmental or Regulatory Matters | ||||||
Estimated undiscounted reserve for environmental liabilities | 105,000 | 105,000 | ||||
Amounts probable of recovery under insurance and from third parties under indemnification agreements | 110,000 | 110,000 | ||||
Estimated size of release (in bbl) | bbl | 2,934 | |||||
Estimated size of release to reach Pacific Ocean (in bbl) | bbl | 598 | |||||
Aggregate total estimated costs | 485,000 | 485,000 | ||||
Recoveries from insurance carriers | 250,000 | |||||
Total release costs probable of recovery | 360,000 | $ 360,000 | ||||
Line 901 Incident | Civil Penalties | ||||||
Legal, Environmental or Regulatory Matters | ||||||
Penalties or compensation paid | 24,000 | |||||
Line 901 Incident | Consent Decree, Compensation for Injuries to, Destruction of, Loss of Use of, Natural Resources | ||||||
Legal, Environmental or Regulatory Matters | ||||||
Penalties or compensation paid | $ 22,325 | |||||
Line 901 Incident | May 2016 Indictment | ||||||
Legal, Environmental or Regulatory Matters | ||||||
Number of felony discharges found guilty | count | 1 | |||||
Number of misdemeanor charges found guilty | count | 8 | |||||
Number of misdemeanor charges found guilty, reporting | count | 1 | |||||
Number of misdemeanor charges found guilty, strict liability discharge | count | 1 | |||||
Number of misdemeanor charges found guilty, strict liability animal takings | count | 6 | |||||
Number of misdemeanor charges found not guilty, strict liability animal takings | count | 1 | |||||
Fines or penalties assessed | $ 3,350 | |||||
Line 901 Incident | Class Action Lawsuits | ||||||
Legal, Environmental or Regulatory Matters | ||||||
Number of cases filed during the period | lawsuit | 9 | |||||
Line 901 Incident | Unitholder Derivative Lawsuits | ||||||
Legal, Environmental or Regulatory Matters | ||||||
Number of cases filed during the period | lawsuit | 4 |
Operating Segments - Segment Fi
Operating Segments - Segment Financial Data (Details) $ in Millions | 3 Months Ended | |
Mar. 31, 2021USD ($)segment | Mar. 31, 2020USD ($) | |
Segment Reporting Information [Line Items] | ||
Operating segments number | segment | 3 | |
Revenues: | ||
Revenues | $ 8,383 | $ 8,269 |
Segment Reporting, Disclosure of Other Information about Entity's Reportable Segments | ||
Equity earnings in unconsolidated entities | 88 | 110 |
Segment Adjusted EBITDA | 546 | 793 |
Maintenance capital | 35 | 51 |
Transportation | ||
Revenues: | ||
Revenues | 137 | 187 |
Segment Reporting, Disclosure of Other Information about Entity's Reportable Segments | ||
Equity earnings in unconsolidated entities | 86 | 108 |
Segment Adjusted EBITDA | 388 | 442 |
Maintenance capital | 26 | 34 |
Facilities | ||
Revenues: | ||
Revenues | 163 | 175 |
Segment Reporting, Disclosure of Other Information about Entity's Reportable Segments | ||
Equity earnings in unconsolidated entities | 2 | 2 |
Segment Adjusted EBITDA | 171 | 210 |
Maintenance capital | 6 | 14 |
Supply and Logistics | ||
Revenues: | ||
Revenues | 8,083 | 7,907 |
Segment Reporting, Disclosure of Other Information about Entity's Reportable Segments | ||
Segment Adjusted EBITDA | (13) | 141 |
Maintenance capital | 3 | 3 |
Operating Segments Excluding Intersegment Elimination | Transportation | ||
Revenues: | ||
Revenues | 234 | 297 |
Operating Segments Excluding Intersegment Elimination | Facilities | ||
Revenues: | ||
Revenues | 163 | 175 |
Operating Segments Excluding Intersegment Elimination | Supply and Logistics | ||
Revenues: | ||
Revenues | 8,083 | 7,907 |
Intersegment | ||
Revenues: | ||
Revenues | (458) | (531) |
Intersegment | Transportation | ||
Revenues: | ||
Revenues | (253) | (282) |
Intersegment | Facilities | ||
Revenues: | ||
Revenues | (108) | (138) |
Intersegment | Supply and Logistics | ||
Revenues: | ||
Revenues | (1) | |
Intersegment Adjustment | ||
Revenues: | ||
Revenues | (97) | (110) |
Operating Segments | ||
Revenues: | ||
Revenues | 8,841 | 8,800 |
Operating Segments | Transportation | ||
Revenues: | ||
Revenues | 487 | 579 |
Operating Segments | Facilities | ||
Revenues: | ||
Revenues | 271 | 313 |
Operating Segments | Supply and Logistics | ||
Revenues: | ||
Revenues | $ 8,083 | $ 7,908 |
Operating Segments - Segment Ad
Operating Segments - Segment Adjusted EBITDA Reconciliation (Details) - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2021 | Mar. 31, 2020 | |
Segment Reporting, Reconciling Item from Segments to Consolidated [Line Items] | ||
Segment Adjusted EBITDA | $ 546 | $ 793 |
Adjustments: | ||
Depreciation and amortization of unconsolidated entities | (20) | (17) |
Gains/(losses) from derivative activities and inventory valuation adjustments | 198 | (30) |
Long-term inventory costing adjustments | 41 | (115) |
Deficiencies under minimum volume commitments, net | 32 | 2 |
Equity-indexed compensation expense | (5) | (4) |
Net gain on foreign currency revaluation | 1 | 13 |
Significant acquisition-related expenses | (3) | |
Unallocated general and administrative expenses | (68) | (70) |
Depreciation and amortization | (178) | (169) |
Gains/(losses) on asset sales and asset impairments, net | (2) | (619) |
Goodwill impairment losses | 0 | (2,515) |
Gain on/(impairment of) investments in unconsolidated entities, net | 0 | (22) |
Interest expense, net | (107) | (108) |
Other expense, net | (60) | (31) |
INCOME/(LOSS) BEFORE TAX | 445 | (2,826) |
Income tax (expense)/benefit | (53) | 134 |
NET INCOME/(LOSS) | 392 | (2,692) |
Net (income)/loss attributable to noncontrolling interests | (322) | 2,111 |
NET INCOME/(LOSS) ATTRIBUTABLE TO PAGP | 70 | (581) |
Unallocated | ||
Adjustments: | ||
Unallocated general and administrative expenses | $ (1) | $ (1) |