DCP Midstream (DCP-PC) 10-K 18 Feb 22 2021 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2021	Feb. 16, 2022	Jun. 30, 2021
Document Type	10-K
Document Annual Report	true
Current Fiscal Year End Date	--12-31
Document Period End Date	Dec. 31, 2021
Document Transition Report	false
Entity File Number	001-32678
Entity Registrant Name	DCP MIDSTREAM, LP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	03-0567133
Entity Address, Address Line One	6900 E. Layton Ave
Entity Address, Address Line Two	Suite 900
Entity Address, City or Town	Denver
Entity Address, State or Province	CO
Entity Address, Postal Zip Code	80237
City Area Code	(303)
Local Phone Number	595-3331
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
Entity Central Index Key	0001338065
ICFR Auditor Attestation Flag	true
Entity Public Float			$ 2,780,516,000
Entity Common Stock, Shares Outstanding		208,378,739
Series B Preferred Limited Partners [Member]
Title of 12(b) Security	7.875% Series B Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units
Trading Symbol	DCP PRB
Security Exchange Name	NYSE
Series C Preferred Limited Partners [Member]
Title of 12(b) Security	7.95% Series C Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units
Trading Symbol	DCP PRC
Security Exchange Name	NYSE
Limited Partners
Title of 12(b) Security	Common Units Representing Limited Partner Interests
Trading Symbol	DCP
Security Exchange Name	NYSE

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2021
Auditor [Line Items]
Auditor Name	Deloitte & Touche LLP
Auditor Location	Denver, Colorado
Auditor Firm ID	34
Gulf Coast Express Pipeline LLC
Auditor [Line Items]
Auditor Name	BDO USA, LLP
Auditor Location	Houston Texas
Auditor Firm ID	243

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 1	$ 52
Accounts receivable:
Trade, net of allowance for credit losses of $2 and $2 million, respectively	1,029	572
Affiliates	389	238
Other	7	10
Inventories	77	38
Unrealized gains on derivative instruments	86	63
Collateral cash deposits	128	14
Other	32	21
Total current assets	1,749	1,008
Property, plant and equipment, net	7,701	7,993
Goodwill		0
Intangible assets, net	39	44
Investments in unconsolidated affiliates	3,578	3,641
Unrealized gains on derivative instruments	10	16
Operating lease assets	104	85
Other long-term assets	199	170
Total assets	13,380	12,957
Accounts payable:
Trade	977	536
Affiliates	205	161
Other	16	23
Current debt	355	505
Unrealized losses on derivative instruments	145	56
Accrued interest	79	85
Accrued taxes	51	59
Accrued wages and benefits	60	70
Capital spending accrual	7	4
Other	115	122
Total current liabilities	2,010	1,621
Long-term debt	5,078	5,119
Unrealized losses on derivative instruments	30	7
Deferred income taxes	34	30
Operating lease liabilities	93	76
Other long-term liabilities	259	243
Total liabilities	7,504	7,096
Equity:
Limited partners (208,373,672 and 208,351,528 common units authorized, issued and outstanding, respectively)	5,106	5,090
Accumulated other comprehensive loss	(6)	(7)
Total partners’ equity	5,851	5,834
Noncontrolling interests	25	27
Total equity	5,876	5,861
Total liabilities and equity	13,380	12,957
Allowance for Doubtful Accounts Receivable, Current	$ 2	$ 2
Common unitholders, units issued (in shares)	208,373,672	208,351,528
Common unitholders, units outstanding (in shares)	208,373,672	208,351,528
Series A Preferred Limited Partners [Member]
Equity:
Preferred Units, Preferred Partners' Capital Accounts	$ 489	$ 489
Total equity	$ 489	$ 489
Preferred Units, Issued	500,000	500,000
Preferred Units, Outstanding	500,000	500,000
Series B Preferred Limited Partners [Member]
Equity:
Preferred Units, Preferred Partners' Capital Accounts	$ 156	$ 156
Total equity	$ 156	$ 156
Preferred Units, Issued	6,450,000	6,450,000
Preferred Units, Outstanding	6,450,000	6,450,000
Series C Preferred Limited Partners [Member]
Equity:
Preferred Units, Preferred Partners' Capital Accounts	$ 106	$ 106
Total equity	$ 106	$ 106
Preferred Units, Issued	4,400,000	4,400,000
Preferred Units, Outstanding	4,400,000	4,400,000

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating revenues:
Trading and marketing gains (losses), net	$ (618)	$ 156	$ (13)
Total operating revenues	10,707	6,302	7,625
Operating costs and expenses:
Operating and maintenance expense	659	607	728
Depreciation and amortization expense	364	376	404
General and administrative expense	223	253	275
Other income (expense)	(5)	15	8
Asset Impairment	31	746	247
Loss on sale of assets, net	5	0	80
Restructuring costs	0	9	11
Total operating costs and expenses	10,542	6,749	7,775
Operating (loss) income	165	(447)	(150)
Earnings from unconsolidated affiliates	535	447	474
Interest expense, net	(299)	(302)	(304)
(Loss) income before income taxes	401	(302)	20
Income tax expense	(6)	0	1
Net income	395	(302)	21
Net income attributable to noncontrolling interests	(4)	(4)	(4)
Net income attributable to partners	391	(306)	17
Series A preferred limited partners' interest in net income	(37)	(37)	(37)
Series B preferred limited partners' interest in net income	(13)	(13)	(13)
Series C preferred limited partners' interest in net income	(9)	(9)	(9)
General partner’s interest in net income	0	0	(118)
Net income allocable to limited partners	$ 332	$ (365)	$ (160)
Net income per limited partner unit — basic and diluted	$ 1.59	$ (1.75)	$ (1.05)
Weighted Average Limited Partnership Units Outstanding, Basic	208.4	208.3	153.1
Weighted Average Limited Partnership Units Outstanding, Diluted	208.6	208.3	153.1
Natural Gas, NGLs and Condensate [Member] | Third Party
Operating revenues:
Sales of natural gas, NGLs and condensate	$ 7,681	$ 4,603	$ 6,023
Operating costs and expenses:
Purchases and related costs	8,093	3,627	4,933
Transportation, Processing and Other [Member]
Operating revenues:
Sales of natural gas, NGLs and condensate	539	455	439
Affiliated Entity | Natural Gas, NGLs and Condensate [Member]
Operating revenues:
Sales of natural gas, NGLs and condensate	3,105	1,088	1,176
Operating costs and expenses:
Purchases and related costs	188	166	223
Affiliated Entity | Transportation Fees
Operating costs and expenses:
Purchases and related costs	$ 984	$ 950	$ 866

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement of Comprehensive Income [Abstract]
Net (loss) income	$ 395	$ (302)	$ 21
Other comprehensive income:
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	1	0	1
Other comprehensive income	1	0	1
Total comprehensive income	396	(302)	22
Total comprehensive income attributable to noncontrolling interests	(4)	(4)	(4)
Total comprehensive income attributable to partners	$ 392	$ (306)	$ 18

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
OPERATING ACTIVITIES:
Net (loss) income	$ 395	$ (302)	$ 21
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	364	376	404
Earnings from unconsolidated affiliates	(535)	(447)	(474)
Distributions from unconsolidated affiliates	604	631	540
Net unrealized (gains) losses on derivative instruments	125	(55)	78
Loss on sale of assets, net	5	0	80
Asset Impairment	31	746	247
Other, net	26	22	21
Change in operating assets and liabilities, which (used) provided cash, net of effects of acquisitions:
Accounts receivable	(605)	62	170
Inventories	(39)	3	9
Accounts payable	478	(47)	(133)
Decrease in Other Operating Assets and Liabilities, Net	(203)	110	(104)
Net cash provided by operating activities	646	1,099	859
INVESTING ACTIVITIES:
Capital expenditures	(108)	(160)	(519)
Payments to Acquire Equity Method Investments	(5)	(107)	(450)
Proceeds from Equity Method Investment, Distribution, Return of Capital	0	6	0
Proceeds from sale of assets	3	2	209
Net cash used in investing activities	(110)	(259)	(760)
FINANCING ACTIVITIES:
Proceeds from debt	4,721	4,407	5,971
Payments of debt	(4,916)	(4,713)	(5,372)
GP and IDR Conversion Costs	0	0	(3)
Distributions to preferred limited partners	(59)	(59)	(59)
Distributions to limited partners and general partner	(325)	(406)	(618)
Payments to Noncontrolling Interests	(6)	(5)	(5)
Payments of Debt Issuance Costs	(6)	(8)	13
Proceeds from (Payments for) Other Financing Activities	0	(1)	0
Net cash provided by (used in) financing activities	(591)	(785)	(99)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect	(55)	55	0
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Beginning Balance	56	1	1
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Ending Balance	1	56	1
Cash and cash equivalents, end of period	1	52	1
Restricted Cash, Current	$ 0	$ 4	$ 0

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity - USD ($) $ in Millions	Total	Series A Preferred Limited Partners [Member]	Series B Preferred Limited Partners [Member]	Series C Preferred Limited Partners [Member]	Limited Partners	General Partner	Accumulated Other Comprehensive (Loss) Income	Noncontrolling Interests
Beginning balance at Dec. 31, 2018	$ 7,297	$ 489	$ 156	$ 106	$ 6,418	$ 107	$ (8)	$ 29
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	21	37	13	9	(160)	118	0	4
Other comprehensive income	1	0	0	0	0	0	1	0
Total Cash Distribution to Unitholders	(677)	(37)	(13)	(9)	(447)	(171)	0	0
Distributions to noncontrolling interests	(5)	0	0	0	0	0	0	(5)
GPIDRConversion	(4)	0	0	0	50	(54)	0	0
Ending balance at Dec. 31, 2019	6,633	489	156	106	5,861	$ 0	(7)	28
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	(302)	37	13	9	(365)		0	4
Other comprehensive income	0
Total Cash Distribution to Unitholders	(465)	(37)	(13)	(9)	(406)		0	0
Distributions to noncontrolling interests	(5)	0	0	0	0		0	(5)
Ending balance at Dec. 31, 2020	5,861	489	156	106	5,090		(7)	27
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	395	37	13	9	332		0	4
Other comprehensive income	1	0	0	0	0		1	0
Total Cash Distribution to Unitholders	(384)	(37)	(13)	(9)	(325)		0	0
Distributions to noncontrolling interests	(6)	0	0	0	0		0	(6)
Employee Benefits and Share-based Compensation	9	0	0	0	9		0	0
Ending balance at Dec. 31, 2021	$ 5,876	$ 489	$ 156	$ 106	$ 5,106		$ (6)	$ 25

Description of Business and Bas

Description of Business and Basis of Presentation (Notes)	12 Months Ended
	Dec. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Description of Business and Basis of Presentation	Description of Business and Basis of Presentation DCP Midstream, LP, with its consolidated subsidiaries, or “ us, ” “ we, ” “ our ” or the “ Partnership ” is a Delaware limited partnership formed in 2005 by DCP Midstream, LLC to own, operate, acquire and develop a diversified portfolio of complementary midstream energy assets. Our Partnership includes our Logistics and Marketing and Gathering and Processing segments. For additional information regarding these segments, see Note 2 3 - Business Segments. Our operations and activities are managed by our general partner, DCP Midstream GP, LP, which in turn is managed by its general partner, DCP Midstream GP, LLC, which we refer to as the General Partner, and which is 100% owned by DCP Midstream, LLC. DCP Midstream, LLC and its subsidiaries and affiliates, collectively referred to as DCP Midstream, LLC, is owned 50% by Phillips 66 and 50% by Enbridge Inc. and its affiliates, or Enbridge. DCP Midstream, LLC directs our business operations through its ownership and control of the General Partner. As of December 31, 2021, DCP Midstream, LLC, together with our general partner, owned approximately 57% of us through limited partner interests. The consolidated financial statements include the accounts of the Partnership and all majority-owned subsidiaries where we have the ability to exercise control. Investments in greater than 20% owned affiliates that are not variable interest entities and where we do not have the ability to exercise control, and investments in less than 20% owned affiliates where we have the ability to exercise significant influence, are accounted for using the equity method. The consolidated financial statements have been prepared in accordance with GAAP. All intercompany balances and transactions have been eliminated in consolidation.

Accounting Policies

Accounting Policies	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Significant Accounting Policies [Text Block]	Summary of Significant Accounting Policies Use of Estimates - Conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and notes. Although these estimates are based on management’s best available knowledge of current and expected future events, actual results could differ from those estimates, which may be significantly impacted by various factors, including those outside of our control, such as the impact of sustained deterioration in commodity prices and volumes, which would negatively impact our results of operations, financial condition and cash flows. Cash, Cash Equivalents, and Restricted Cash - We consider investments in highly liquid financial instruments purchased with an original stated maturity of 90 days or less and temporary investments of cash in short-term money market securities to be cash equivalents. Restricted cash primarily consists of amounts held in our non-qualified deferred compensation plan. Restricted cash is excluded from cash and cash equivalents and is included in other current or long-term assets. Allowance for Credit Losses - Management estimates the amount of required allowances for credit losses based upon our assessment of various factors, including historical loss rates, the age of the accounts receivable balances, the credit quality of our customers, current economic conditions, reasonable and supportable forecasts of future economic conditions, and other relevant factors that may affect our ability to collect from customers. Inventories - Inventories, which consist primarily of NGLs and natural gas, are recorded at the lower of weighted-average cost or net realizable value. Transportation costs are included in inventory. Accounting for Risk Management Activities and Financial Instruments - Non-trading energy commodity derivatives are designated as a hedge of a forecasted transaction or future cash flow (cash flow hedge), a hedge of a recognized asset, liability or firm commitment (fair value hedge), or normal purchases or normal sales. The remaining non-trading derivatives, which are related to asset-based activities for which the normal purchase or normal sale exception is not elected, are recorded at fair value in the consolidated balance sheets as unrealized gains or unrealized losses in derivative instruments, with changes in the fair value recognized in the consolidated statements of operations. For each derivative, the accounting method and presentation of gains and losses or revenue and expense in the consolidated statements of operations are as follows: Classification of Contract Accounting Method Presentation of Gains & Losses or Revenue & Expense Trading Derivatives Mark-to-market method (a) Net basis in trading and marketing gains and losses Non-Trading Derivatives: Cash Flow Hedge Hedge method (b) Gross basis in the same consolidated statements of operations category as the related hedged item Fair Value Hedge Hedge method (b) Gross basis in the same consolidated statements of operations category as the related hedged item Normal Purchases or Normal Sales Accrual method (c) Gross basis upon settlement in the corresponding consolidated statements of operations category based on purchase or sale Other Non-Trading Derivative Activity Mark-to-market method (a) Net basis in trading and marketing gains and losses, net (a) Mark-to-market method - An accounting method whereby the change in the fair value of the asset or liability is recognized in the consolidated statements of operations in trading and marketing gains and losses, net during the current period. (b) Hedge method - An accounting method whereby the change in the fair value of the asset or liability is recorded in the consolidated balance sheets as unrealized gains or unrealized losses on derivative instruments. For cash flow hedges, there is no recognition in the consolidated statements of operations for the effective portion until the service is provided or the associated delivery impacts earnings. For fair value hedges, the change in the fair value of the asset or liability, as well as the offsetting changes in value of the hedged item, are recognized in the consolidated statements of operations in the same category as the related hedged item. (c) Accrual method - An accounting method whereby there is no recognition in the consolidated balance sheets or consolidated statements of operations for changes in fair value of a contract until the service is provided or the associated delivery impacts earnings. Cash Flow and Fair Value Hedges - For derivatives designated as a cash flow hedge or a fair value hedge, we maintain formal documentation of the hedge. In addition, we formally assess both at the inception of the hedging relationship and on an ongoing basis, whether the hedge contract is highly effective in offsetting changes in cash flows or fair values of hedged items. All components of each derivative gain or loss are included in the assessment of hedge effectiveness, unless otherwise noted. The fair value of a derivative designated as a cash flow hedge is recorded in the consolidated balance sheets as unrealized gains or unrealized losses on derivative instruments. The change in fair value of the effective portion of a derivative designated as a cash flow hedge is recorded in partners’ equity in accumulated other comprehensive income, or AOCI, and the ineffective portion is recorded in the consolidated statements of operations. During the period in which the hedged transaction impacts earnings, amounts in AOCI associated with the hedged transaction are reclassified to the consolidated statements of operations in the same line item as the item being hedged. Hedge accounting is discontinued prospectively when it is determined that the derivative no longer qualifies as an effective hedge, or when it is probable that the hedged transaction will not occur. When hedge accounting is discontinued because the derivative no longer qualifies as an effective hedge, the derivative is subject to the mark-to-market accounting method prospectively. The derivative continues to be carried on the consolidated balance sheets at its fair value; however, subsequent changes in its fair value are recognized in current period earnings. Gains and losses related to discontinued hedges that were previously accumulated in AOCI will remain in AOCI until the hedged transaction impacts earnings, unless it is probable that the hedged transaction will not occur, in which case, the gains and losses that were previously deferred in AOCI will be immediately recognized in current period earnings. The fair value of a derivative designated as a fair value hedge is recorded for balance sheet purposes as unrealized gains or unrealized losses on derivative instruments. We recognize the gain or loss on the derivative instrument, as well as the offsetting loss or gain on the hedged item in earnings in the current period. All derivatives designated and accounted for as fair value hedges are classified in the same category as the item being hedged in the results of operations. Valuation - When available, quoted market prices or prices obtained through external sources are used to determine a contract’s fair value. For contracts with a delivery location or duration for which quoted market prices are not available, fair value is determined based on pricing models developed primarily from historical relationships with quoted market prices and the expected relationship with quoted market prices. Values are adjusted to reflect the credit risk inherent in the transaction as well as the potential impact of liquidating open positions in an orderly manner over a reasonable time period under current conditions. Changes in market prices and management estimates directly affect the estimated fair value of these contracts. Accordingly, it is reasonably possible that such estimates may change in the near term. Property, Plant and Equipment - Property, plant and equipment are recorded at historical cost. The cost of maintenance and repairs, which are not significant improvements, are expensed when incurred. Depreciation is computed using the straight-line method over the estimated useful lives of the assets. Capitalized Interest - We capitalize interest during construction of major projects. Interest is calculated on the monthly outstanding capital balance and ceases in the month that the asset is placed into service. We also capitalize interest on our equity method investments which are devoting substantially all efforts to establishing a new business and have not yet begun planned principal operations. Capitalization ceases when the investee commences planned principal operations. The rates used to calculate capitalized interest are the weighted-average cost of debt, including the impact of interest rate swaps. Asset Retirement Obligations - Our asset retirement obligations relate primarily to the retirement of various gathering pipelines and processing facilities and obligations related to right-of-way and land easement agreements. We adjust our asset retirement obligation each quarter for any liabilities incurred or settled during the period, accretion expense and any revisions made to the estimated cash flows. Asset retirement obligations associated with tangible long-lived assets are recorded at fair value in the period in which they are incurred, if a reasonable estimate of fair value can be made, and added to the carrying amount of the associated asset. This additional carrying amount is then depreciated over the life of the asset. The liability is determined using a credit-adjusted risk free interest rate, and accretes due to the passage of time based on the time value of money until the obligation is settled. Intangible Assets - Intangible assets consist of customer contracts, including commodity purchase, transportation and processing contracts, and related relationships. These intangible assets are amortized on a straight-line basis over the period of expected future benefit. Intangible assets are removed from the gross carrying amount and the total of accumulated amortization in the period in which they become fully amortized. Investments in Unconsolidated Affiliates - We use the equity method to account for investments in greater than 20% owned affiliates. We evaluate our investments in unconsolidated affiliates for impairment whenever events or changes in circumstances indicate a decline in value of such investments has occurred that is other than temporary. When there is evidence of impairment that is other than temporary, we compare the estimated fair value of the investment to the carrying value of the investment to determine whether impairment has occurred. We assess the fair value of our investments in unconsolidated affiliates using commonly accepted techniques, and may use more than one method, but is primarily measured with discounted cash flow models. If the estimated fair value is less than the carrying value, the excess of the carrying value over the estimated fair value is recognized as an impairment loss. Long-Lived Assets - We periodically evaluate whether the carrying value of long-lived assets, including intangible assets, has been impaired when circumstances indicate the carrying value of those assets may not be recoverable. This evaluation is based on undiscounted cash flow projections. The carrying amount is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. We consider various factors when determining if these assets should be evaluated for impairment, including but not limited to: • significant adverse change in legal factors or business climate; • a current-period operating or cash flow loss combined with a history of operating or cash flow losses, or a projection or forecast that demonstrates continuing losses associated with the use of a long-lived asset; • an accumulation of costs significantly in excess of the amount originally expected for the acquisition or construction of a long-lived asset; • significant adverse changes in the extent or manner in which an asset is used, or in its physical condition; • significant adverse change in the market value of an asset; or • a current expectation that, more likely than not, an asset will be sold or otherwise disposed of before the end of its estimated useful life. If the carrying value is not recoverable, the impairment loss is measured as the excess of the asset’s carrying value over its fair value. We assess the fair value of long-lived assets using commonly accepted techniques, and may use more than one method, including, but not limited to, recent third party comparable sales and discounted cash flow models. Significant changes in market conditions resulting from events such as the condition of an asset or a change in management’s intent to utilize the asset would generally require management to reassess the cash flows related to the long-lived assets. A period of lower commodity prices may adversely affect our estimate of future operating results, which could result in future impairment due to the potential impact on our operations and cash flows. Leases - Our leasing activity primarily consists of transportation agreements, office space, vehicles, and field equipment. We determine if an arrangement is an operating or finance lease at inception. Right of use assets represent our right to use an underlying asset for the lease term when we control the use of the asset by obtaining substantially all of the economic benefits of the asset and direct the use of the asset. Lease liabilities represent our obligation to make lease payments arising from the lease. Right of use assets and lease liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. The interest rate used to calculate the present value of lease payments is the rate implicit in the lease when determinable or our incremental borrowing rate. Our incremental borrowing rate is primarily based on our collateralized borrowing rate when such borrowings exist or an estimated collateralized borrowing rate based on independent third party quotes when such borrowings do not exist. Our lease terms may include options to extend or terminate the lease when it is reasonably certain that we will exercise that option. Operating lease expense is recognized on a straight-line basis over the lease term. Finance lease expense is recognized based on the effective-interest method and amortization of the right of use asset is recognized based on the straight-line method. Practical expedients - We apply certain practical expedients in Accounting Standards Codification ("ASC") 842, Leases and we do not recognize ROU assets and lease liabilities for short-term leases and, instead, record them in a manner similar to operating leases under legacy lease accounting guidelines. A short-term lease is one with a maximum lease term of 12 months or less and does not include a purchase option the lessee is reasonably certain to exercise. We combine lease and nonlease components relating to our office and warehouse leases, as applicable. Unamortized Debt Discount and Expense - Discounts and expenses incurred with the issuance of long-term debt are amortized over the term of the debt using the effective interest method. The discounts and unamortized expenses are recorded on the consolidated balance sheets within the carrying amount of long-term debt. Noncontrolling Interest - Noncontrolling interest represents any third party or affiliate interest in non-wholly owned entities that we consolidate. For financial reporting purposes, the assets and liabilities of these entities are consolidated with those of our own, with any third party or affiliate interest in our consolidated balance sheet amounts shown as noncontrolling interest in equity. Distributions to and contributions from noncontrolling interests represent cash payments to and cash contributions from, respectively, such third party and affiliate investors. Revenue Recognition - Our operating revenues are primarily derived from the following activities: • sales of natural gas, NGLs and condensate; • services related to gathering, compressing, treating, and processing natural gas; and • services related to transportation and storage of natural gas and NGLs. Sales of natural gas, NGLs and condensate - We sell our commodities to a variety of customers ranging from large, multi-national petrochemical and refining companies to regional retail propane distributors. We recognize revenue from commodity sales at the point in time when control is obtained by the customer. Generally, the transaction price is determined at the time of each delivery as the variability of commodity pricing is resolved. Customers usually pay monthly based on the products purchased the previous month. Sales of natural gas, NGLs and condensate include physical sales contracts which qualify as financial derivative instruments, and buy-sell and exchange transactions which involve purchases and sales of inventory with the same counterparty that are legally contingent or in contemplation of one another as a single transaction on a combined net basis. Neither of these types of arrangements are contracts with customers within the scope of Financial Accounting Standards Board, or "FASB", Accounting Standards Update, or "ASU", 2014-09 Revenue from Contracts with Customers, or "Topic 606". Gathering, compressing, treating and processing natural gas - For natural gas gathering and processing activities, we receive either fees and/or a percentage of proceeds from commodity sales as payment for these services, depending on the type of contract. For gathering and processing agreements within the scope of Topic 606, we recognize the revenue associated with our services when the gas is gathered, treated or processed at our facilities. Under fee-based contracts, we receive a fee for our services based on throughput volumes. Under percent-of-proceeds contracts, we receive either an agreed upon percentage of the actual proceeds received from our sale of the residue natural gas and NGLs or an agreed upon percentage based on index related prices for the natural gas and NGLs. Our percent-of-proceeds contracts may also include a fee-based component. Transportation and storage - Revenue from transportation and storage agreements is recognized based on contracted volumes transported and stored in the period the services are provided. Our service contracts sometimes have terms that extend beyond one year, and are recognized over time. The performance obligation for most of our service contracts encompasses a series of distinct services performed on discrete daily quantities of natural gas or NGLs for purposes of allocating variable consideration and recognizing revenue while the customer simultaneously receives and consumes the benefits of the services provided. Revenue is recognized over time consistent with the transfer of goods or services over time to the customer based on daily volumes delivered or stored. Consideration is generally variable, and the transaction price cannot be determined at the inception of the contract, because the volume of natural gas or NGLs for which the service is provided is only specified on a daily or monthly basis. The transaction price is determined at the time the service is provided and the uncertainty is resolved. Customers usually pay monthly based on the services performed the previous month. Purchase arrangements - Under purchase arrangements, we purchase natural gas at either the wellhead or the tailgate of a plant. These purchase arrangements represent an arrangement with a supplier and are recorded in “Purchases and related costs”. Often, we earn fees for services performed prior to taking control of the product in these arrangements and service revenue is recorded for these fees. Revenue generated from the sale of product obtained in these purchase arrangements are reported as “Sales of natural gas, NGLs and condensate” on the consolidated statements of operations and are recognized on a gross basis as we purchase and take control of the product prior to sale and are the principal in the transaction. Practical expedients - We apply certain practical expedients in Topic 606 and do not disclose information about transaction prices allocated to remaining performance obligations that have original expected durations of one year or less, nor do we disclose information about transaction prices allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Contract liabilities - We have contracts with customers whereby the customer reimburses us for costs to construct certain connections to our operating assets. These agreements are typically entered into in contemplation with gathering and processing agreements and transportation agreements with customers, and are part of the consideration of the contract. We record these payments as deferred revenue which are amortized into revenue over the expected contract term. Purchases and related costs - Purchases and related costs primarily includes (i) the cost of purchased commodities, including NGLs, natural gas and condensate, and (ii) fees incurred for transportation and fractionation of commodities. Significant Customers - There were no third party customers that accounted for more than 10% of total operating revenues for the years ended December 31, 2021, 2020 and 2019. We had significant transactions with affiliates for the years ended December 31, 2021, 2020 and 2019. Environmental Expenditures - Environmental expenditures are expensed or capitalized as appropriate, depending upon the future economic benefit. Expenditures that relate to an existing condition caused by past operations and that do not generate current or future revenue are expensed. Liabilities for these expenditures are recorded on an undiscounted basis when environmental assessments and/or clean-ups are probable and the costs can be reasonably estimated. Equity-Based Compensation - Equity classified awards are measured at their grant date fair value, which is recognized on a straight line basis over the requisite service or vesting period. Equity classified awards are expected to result in the issuance of common units upon vesting. Liability classified equity-based compensation cost is remeasured at each reporting date at fair value, based on the closing security price, and is recognized as expense over the requisite service period. Compensation expense for awards with graded vesting provisions is recognized on a straight-line basis over the requisite service period of each separately vesting portion of the award. Income Taxes - We are structured as a master limited partnership which is a pass-through entity for federal income tax purposes. Our income tax expense includes certain jurisdictions, including state, local, franchise and margin taxes of the master limited partnership and subsidiaries. We follow the asset and liability method of accounting for income taxes. Under this method, deferred income taxes are recognized for the tax consequences of temporary differences between the financial statement carrying amounts and the tax basis of the assets and liabilities. Our taxable income or loss, which may vary substantially from the net income or loss reported in the consolidated statements of operations, is proportionately included in the federal income tax returns of each partner.

Recent Accounting Pronouncement

Recent Accounting Pronouncements (Notes)	12 Months Ended
	Dec. 31, 2021
Recent Accounting Pronouncements, Policy [Abstract]
Recent Accounting Pronouncements and Changes in Accounting Principles [Text Block]	Recent Accounting Pronouncements FASB ASU, 2020-04 “ Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting ” or ASU 2020-04 - In March 2020, the FASB issued ASU 2020-04, which provides optional expedients and exceptions for applying GAAP to contract modifications, hedging relationships, and other transactions that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. This ASU is effective for interim and annual reporting periods that include or are subsequent to March 12, 2020. We adopted this ASU on March 12, 2020 and it did not have a material impact on our consolidated financial statements. The FASB has issued certain accounting updates which were assessed and either determined to be not applicable or are not expected to have a significant impact on our financial statements.

Dispositions (Notes)

Dispositions (Notes)	12 Months Ended
	Dec. 31, 2021
Disposal Group, Not Discontinued Operation, Disposal Disclosures [Abstract]
Dispositions	Dispositions During 2021 we divested several non-core assets in our Midcontinent region of our Gathering and Processing segment and in West Texas in our Logistics and Marketing segment. We received proceeds of $3 million and recognized a net loss on sale of assets and businesses of $5 million during 2021. On January 30, 2019, we entered into a purchase and sale agreement with NGL Energy Partners LP to sell Gas Supply Resources, our wholesale propane business primarily consisting of seven natural gas liquids terminals in the Eastern United States within our Logistics and Marketing segment for a purchase price of $90 million. Net proceeds received were approximately $103 million due to customary purchase price adjustments and a loss of $9 million was recognized. The transaction closed effective March 1, 2019. In addition to the sale of Gas Supply Resources, we divested several non-core assets in our Midcontinent and Permian regions. We received proceeds of $106 million and recognized a net loss on sale of assets and businesses of $71 million during 2019.

Revenue Recognition (Notes)

Revenue Recognition (Notes)	12 Months Ended
	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Revenue from External Customers by Products and Services [Table Text Block]	Revenue RecognitionWe disaggregate our revenue from contracts with customers by type of contract for each of our reportable segments, as we believe it best depicts the nature, timing and uncertainty of our revenue and cash flows. The following tables set forth our revenue by those categories: Year Ended December 31, 2021 Logistics and Marketing Gathering and Processing Eliminations Total (millions) Sales of natural gas $ 3,798 $ 2,824 $ (2,614) $ 4,008 Sales of NGLs and condensate (a) 6,133 3,952 (3,307) 6,778 Transportation, processing and other 65 474 — 539 Trading and marketing losses, net (b) (262) (356) — (618) Total operating revenues $ 9,734 $ 6,894 $ (5,921) $ 10,707 (a) Includes $2,111 million for the year ended December 31, 2021 of revenues from physical sales contracts and buy-sell exchange transactions in our Logistics and Marketing segment, which is net of $2,590 million of buy-sell purchases related to buy-sell revenues of $2,857 million which are not within the scope of FASB ASC 606 "Revenue from Contractors with Customer" ("Topic 606"). (b) Not within the scope of Topic 606. Year Ended December 31, 2020 Logistics and Marketing Gathering and Processing Eliminations Total (millions) Sales of natural gas $ 1,786 $ 1,384 $ (1,263) $ 1,907 Sales of NGLs and condensate (a) 3,569 1,658 (1,443) 3,784 Transportation, processing and other 51 405 (1) 455 Trading and marketing gains, net (b) 124 32 — 156 Total operating revenues $ 5,530 $ 3,479 $ (2,707) $ 6,302 (a) Includes $1,786 million of revenues for the year ended December 31, 2020, from physical sales contracts and buy-sell exchange transactions in our Logistics and Marketing segment, which is net of $1,004 million of buy-sell purchases related to buy-sell revenues of $1,300 million which are not within the scope of Topic 606. (b) Not within the scope of Topic 606. Year Ended December 31, 2019 Logistics and Marketing Gathering and Processing Eliminations Total (millions) Sales of natural gas $ 2,098 $ 1,734 $ (1,525) $ 2,307 Sales of NGLs and condensate (a) 4,744 2,171 (2,023) 4,892 Transportation, processing and other 46 395 (2) 439 Trading and marketing (losses) gains, net (b) (32) 19 — (13) Total operating revenues $ 6,856 $ 4,319 $ (3,550) $ 7,625 (a) Includes $3,236 million for the year ended December 31, 2019 of revenues from physical sales contracts and buy-sell exchange transactions in our Logistics and Marketing segment, which are not within the scope of Topic 606. (b) Not within the scope of Topic 606. The revenue expected to be recognized in the future related to performance obligations that are not satisfied is approximately $442 million as of December 31, 2021. Our remaining performance obligations primarily consist of minimum volume commitment fee arrangements and are expected to be recognized through 2031 with a weighted average remaining life of three years as of December 31, 2021. As a practical expedient permitted by Topic 606, this amount excludes variable consideration as well as remaining performance obligations that have original expected durations of one year or less, as applicable. Our remaining performance obligations also exclude estimates of variable rate escalation clauses in our contracts with customers.

Contract Liabilities (Notes)

Contract Liabilities (Notes)	12 Months Ended
	Dec. 31, 2021
Contract Assets and Liabilities [Abstract]
Contract Assets and Liabilities [Text Block]	Contract LiabilitiesOur contract liabilities consist of deferred revenue received from reimbursable projects. The noncurrent portion of deferred revenue is included in other long-term liabilities on our consolidated balance sheets. The following table summarizes changes in contract liabilities included in our consolidated balance sheets: December 31, 2021 2020 (millions) Balance, beginning of period $ 35 $ 33 Additions 1 3 Revenue recognized (a) (2) (1) Balance, end of period $ 34 $ 35 (a) Deferred revenue recognized is included in transportation, processing and other on the consolidated statements of operations. The contract liabilities disclosed in the table above will be recognized as revenue as the obligations are satisfied over their average remaining contract life, which is 35 years as of December 31, 2021.

Agreements and Transactions wit

Agreements and Transactions with Affiliates	12 Months Ended
	Dec. 31, 2021
Related Party Transactions [Abstract]
Agreements and Transactions with Affiliates	Agreements and Transactions with Affiliates DCP Midstream, LLC Services Agreement and Other General and Administrative Charges Under the Services and Employee Secondment Agreement (the “Services Agreement ” ), we are required to reimburse DCP Midstream, LLC for costs, expenses, and expenditures incurred or payments made on our behalf for general and administrative functions including, but not limited to, legal, accounting, compliance, treasury, insurance administration and claims processing, risk management, health, safety and environmental, information technology, human resources, benefit plan maintenance and administration, credit, payroll, internal audit, taxes and engineering, as well as salaries and benefits of seconded employees, insurance coverage and claims, capital expenditures, maintenance and repair costs and taxes. There is no limit on the reimbursements we make to DCP Midstream, LLC under the Services Agreement for costs, expenses and expenditures incurred or payments made on our behalf. The following table summarizes employee related costs that were charged by DCP Midstream, LLC to the Partnership that are included in the consolidated statements of operations: Year Ended December 31, 2021 2020 2019 (millions) Employee related costs charged by DCP Midstream, LLC Operating and maintenance expense $ 157 $ 160 $ 197 General and administrative expense $ 149 $ 165 $ 189 Restructuring costs $ — $ 9 $ 11 Phillips 66 and its Affiliates We sell a portion of our residue gas and NGLs to and purchase NGLs from Phillips 66 and its respective affiliates. We anticipate continuing to sell commodities to and purchase commodities from Phillips 66 and its affiliates in the ordinary course of business. Enbridge and its Affiliates We purchase NGLs from Enbridge and its affiliates. We anticipate continuing to purchase commodities from Enbridge and its affiliates in the ordinary course of business. Unconsolidated Affiliates We have entered into transportation agreements with DCP Sand Hills Pipeline, LLC, or Sand Hills, DCP Southern Hills Pipeline, LLC, or Southern Hills, Front Range Pipeline LLC, or Front Range, Texas Express Pipeline LLC, or Texas Express, Gulf Coast Express Pipeline, LLC, or Gulf Coast and Cheyenne Connector LLC, or Cheyenne Connector. Under the terms of these agreements, which expire between 2028 and 2030, we have committed to transport minimum throughput volumes at rates defined in each of the pipelines’ respective tariffs. We sell a portion of our residue gas and NGLs to, purchase natural gas and other NGL products from, provide gathering and transportation services to, and receive transportation services from unconsolidated affiliates. We anticipate continuing to purchase and sell commodities and receive and provide services to unconsolidated affiliates in the ordinary course of business. Under the terms of the Sand Hills LLC Agreement and the Southern Hills LLC Agreement, or the Sand Hills and Southern Hills LLC Agreements, Sand Hills and Southern Hills are required to reimburse us for any direct costs or expenses (other than general and administration services) which we incur on behalf of Sand Hills and Southern Hills. Additionally, Sand Hills and Southern Hills each pay us an annual service fee of $5 million, for centralized corporate functions provided by us as operator of Sand Hills and Southern Hills, including legal, accounting, cash management, insurance administration and claims processing, risk management, health, safety and environmental, information technology, human resources, credit, payroll, taxes and engineering. Except with respect to the annual service fee, there is no limit on the reimbursements Sand Hills and Southern Hills make to us under the Sand Hills and Southern Hills LLC Agreements for other expenses and expenditures which we incur on behalf of Sand Hills or Southern Hills. Summary of Transactions with Affiliates The following table summarizes our transactions with affiliates: Year Ended December 31, 2021 2020 2019 (millions) Phillips 66 (including its affiliates): Sales of natural gas, NGLs and condensate to affiliates $ 3,000 $ 1,037 $ 1,140 Purchases and related costs from affiliates $ 62 $ 96 $ 142 Transportation and related costs from affiliates $ 158 $ 113 $ 67 Operating and maintenance and general administrative expenses $ 14 $ 11 $ 13 Enbridge (including its affiliates): Sales of natural gas, NGLs and condensate to affiliates $ 2 $ 2 $ (2) Purchases and related costs from affiliates $ 40 $ 20 $ 26 Transportation and related costs from affiliates $ 1 $ 1 $ 1 Operating and maintenance and general administrative expenses $ 1 $ 2 $ 2 Unconsolidated affiliates: Sales of natural gas, NGLs and condensate to affiliates $ 103 $ 49 $ 38 Transportation, processing, and other to affiliates $ 18 $ 13 $ 4 Purchases and related costs from affiliates $ 86 $ 50 $ 70 Transportation and related costs from affiliates $ 825 $ 836 $ 783 We had balances with affiliates as follows: December 31, 2021 December 31, 2020 (millions) Phillips 66 (including its affiliates): Accounts receivable $ 361 $ 217 Accounts payable $ 114 $ 89 Other assets $ 1 $ 1 Enbridge (including its affiliates): Accounts payable $ 4 $ 2 Unconsolidated affiliates: Accounts receivable $ 28 $ 21 Accounts payable $ 87 $ 70

Inventories (Notes)

Inventories (Notes)	12 Months Ended
	Dec. 31, 2021
Inventory Disclosure [Abstract]
Inventories	Inventories Inventories were as follows: December 31, 2021 December 31, 2020 (millions) Natural gas $ 43 $ 18 NGLs 34 20 Total inventories $ 77 $ 38 We recognize lower of cost or net realizable value adjustments when the carrying value of our inventories exceeds their net realizable value. These non-cash charges are a component of purchases and related costs in the consolidated statements of operations. We recognized zero, $6 million, and $10 million of lower of cost or net realizable value adjustments for the years ended December 31, 2021, 2020, and 2019, respectively.

Property, Plant and Equipment (

Property, Plant and Equipment (Notes)	12 Months Ended
	Dec. 31, 2021
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment A summary of property, plant and equipment by classification is as follows: Depreciable December 31, 2021 December 31, 2020 (millions) Gathering and transmission systems 20 — 50 Years $ 7,645 $ 7,680 Processing, storage and terminal facilities 35 — 60 Years 5,057 4,986 Other 3 — 30 Years 585 585 Finance lease assets 2 — 5 Years 28 25 Construction work in progress 103 144 Property, plant and equipment 13,418 13,420 Accumulated depreciation (5,717) (5,427) Property, plant and equipment, net $ 7,701 $ 7,993 Capitalized interest on construction projects was $2 million, $7 million, and $13 million for the years ended December 31, 2021, 2020, and 2019, respectively. Depreciation expense was $358 million, $370 million, and $396 million for the years ended December 31, 2021, 2020, and 2019, respectively. Asset Retirement Obligations We identified various assets as having an indeterminate life, for which there is no requirement to establish a fair value for future retirement obligations associated with such assets. These assets include certain pipelines, gathering systems and processing facilities. A liability for these asset retirement obligations will be recorded only if and when a future retirement obligation with a determinable life is identified. These assets have an indeterminate life because they are owned and will operate for an indeterminate future period when properly maintained. Additionally, if the portion of an owned plant containing asbestos were to be modified or dismantled, we would be legally required to remove the asbestos. We currently have no plans to take actions that would require the removal of the asbestos in these assets. Accordingly, the fair value of the asset retirement obligation related to this asbestos cannot be estimated and no obligation has been recorded. The following table summarizes changes in the asset retirement obligations included in our balance sheets: December 31, 2021 (a) 2020 (a) (millions) Balance, beginning of period $ 150 $ 141 Accretion expense 10 $ 9 Dispositions (2) $ — Balance, end of period $ 158 $ 150 (a) Asset retirement obligations are included in other long-term liabilities in the consolidated balance sheets. Accretion expense is recorded within operating and maintenance expense in our consolidated statement of operations. Accretion expense for the year ended December 31, 2019 was $9 million.

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Notes)	12 Months Ended
	Dec. 31, 2021
Goodwill Disclosure [Abstract]
Goodwill Disclosure [Text Block]	Goodwill and Intangible Assets During the first quarter of 2020, certain areas of our business, as well as those of other midstream companies in our peer group, suffered a significant decline in market value, primarily as result of significantly depressed commodity prices and demand for oil and gas products. This was the result of both a reduction in estimated enterprise value and an increase to our estimated discount rate. We performed an analysis to determine the estimated fair value of the North reporting unit as of March 31, 2020 and concluded that its carrying value exceeded its fair value by more than the recorded amount of goodwill within the reporting unit, resulting in an impairment charge of $159 million. The significant decline in commodity prices and demand for oil and gas products decreased forecasted cash flows such that, while in excess of asset book value on an undiscounted basis, they were not sufficient to recover the value of allocated goodwill in the North reporting unit. We primarily used a discounted cash flow analysis, supplemented by a market approach analysis, to perform our goodwill assessment. Key assumptions in the analysis include the use of an appropriate discount rate, terminal year multiples, and estimated future cash flows, including an estimate of operating and general and administrative costs. In estimating cash flows, we incorporate current market information (including forecasted volumes and commodity prices), as well as historical and other factors. The carrying amount of goodwill in each of our reportable segments was as follows: Gathering and Processing Logistics and Marketing Total (millions) Balance, December 31, 2019 $ 159 $ — $ 159 Impairment (159) — (159) Balance, December 31, 2020 $ — $ — $ — Intangible assets consist of customer contracts, including commodity purchase, transportation and processing contracts and related relationships. The gross carrying amount and accumulated amortization of these intangible assets are included in the accompanying consolidated balance sheets as intangible assets, net, and are as follows: December 31, December 31, 2021 2020 (millions) Gross carrying amount $ 110 $ 111 Accumulated amortization (71) (67) Intangible assets, net $ 39 $ 44 We recorded amortization expense of $6 million, $6 million and $8 million for the years ended December 31, 2021, 2020, and 2019, respectively. As of December 31, 2021, the remaining amortization periods ranged from approximately 1 year to 13 years, with a weighted-average remaining period of approximately 10 years. Estimated future amortization for these intangible assets is as follows: Estimated Future Amortization (millions) 2022 $ 4 2023 4 2024 4 2025 4 2026 4 Thereafter 19 Total $ 39

Investments in Unconsolidated A

Investments in Unconsolidated Affiliates	12 Months Ended
	Dec. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Investments in Unconsolidated Affiliates	Investments in Unconsolidated Affiliates The following table summarizes our investments in unconsolidated affiliates: Carrying Value as of Percentage December 31, December 31, 2020 (millions) DCP Sand Hills Pipeline, LLC 66.67% $ 1,703 $ 1,723 DCP Southern Hills Pipeline, LLC 66.67% 728 734 Gulf Coast Express LLC 25.00% 422 436 Front Range Pipeline LLC 33.33% 195 198 Texas Express Pipeline LLC 10.00% 94 97 Mont Belvieu 1 Fractionator 20.00% 6 7 Discovery Producer Services LLC 40.00% 231 244 Cheyenne Connector, LLC 50.00% 148 152 Mont Belvieu Enterprise Fractionator 12.50% 28 26 Panola Pipeline Company, LLC 15.00% 20 21 Other Various 3 3 Total investments in unconsolidated affiliates $ 3,578 $ 3,641 The following table represents the excess (deficit) of the carrying amount of the investment over (under) the underlying equity of our investments in unconsolidated affiliates as of December 31, 2021 and 2020: Excess (Deficit) of Carrying Value over (under) Underlying Equity in Unconsolidated Affiliates December 31, 2021 December 31, 2020 (millions) DCP Sand Hills Pipeline, LLC $ 590 $ 605 DCP Southern Hills Pipeline, LLC $ 132 $ 135 Gulf Coast Express Pipeline LLC $ 1 $ 1 Front Range Pipeline LLC $ 4 $ 4 Texas Express Pipeline LLC $ 2 $ 2 Discovery Producer Services LLC $ 1 $ (8) Cheyenne Connector, LLC $ 4 $ 4 Carrying amounts in excess or deficit of the underlying equity of our unconsolidated affiliates are amortized over the life of the underlying long-lived assets of the affiliate. Earnings from investments in unconsolidated affiliates were as follows: Year Ended December 31, 2021 2020 2019 (millions) DCP Sand Hills Pipeline, LLC $ 274 $ 279 $ 287 DCP Southern Hills Pipeline, LLC 91 78 77 Gulf Coast Express LLC 63 66 27 Front Range Pipeline LLC 38 38 32 Texas Express Pipeline LLC 19 18 16 Mont Belvieu 1 Fractionator 17 12 13 Discovery Producer Services LLC (a) 16 (63) 6 Cheyenne Connector, LLC 12 6 — Mont Belvieu Enterprise Fractionator 3 11 14 Other 2 2 2 Total earnings from unconsolidated affiliates $ 535 $ 447 $ 474 (a) See Note 12 for further discussion. The following tables summarize the combined financial information of our investments in unconsolidated affiliates: Year Ended December 31, 2021 2020 2019 (millions) Statements of operations: Operating revenue $ 2,110 $ 2,049 $ 1,798 Operating expenses $ 844 $ 746 $ 695 Net income $ 1,261 $ 1,297 $ 1,103 December 31, December 31, (millions) Balance sheets: Current assets $ 429 $ 355 Long-term assets 7,277 7,510 Current liabilities (200) (177) Long-term liabilities (254) (258) Net assets $ 7,252 $ 7,430

Fair Value Measurement (Notes)

Fair Value Measurement (Notes)	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Derivatives and Fair Value	Fair Value Measurement Determination of Fair Value Below is a general description of our valuation methodologies for derivative financial assets and liabilities which are measured at fair value. Fair values are generally based upon quoted market prices or prices obtained through external sources, where available. If listed market prices or quotes are not available, we determine fair value based upon a market quote, adjusted by other market-based or independently sourced market data such as historical commodity volatilities, crude oil future yield curves, and/or counterparty specific considerations. These adjustments result in a fair value for each asset or liability under an “exit price” methodology, in line with how we believe a marketplace participant would value that asset or liability. Fair values are adjusted to reflect the credit risk inherent in the transaction as well as the potential impact of liquidating open positions in an orderly manner over a reasonable time period under current conditions. These adjustments may include amounts to reflect counterparty credit quality, the effect of our own creditworthiness, and/or the liquidity of the market. • Counterparty credit valuation adjustments are necessary when the market price of an instrument is not indicative of the fair value as a result of the credit quality of the counterparty. Generally, market quotes assume that all counterparties have near zero, or low, default rates and have equal credit quality. Therefore, an adjustment may be necessary to reflect the credit quality of a specific counterparty to determine the fair value of the instrument. We record counterparty credit valuation adjustments on all derivatives that are in a net asset position as of the measurement date in accordance with our established counterparty credit policy, which takes into account any collateral margin that a counterparty may have posted with us as well as any letters of credit that they have provided. • Entity valuation adjustments are necessary to reflect the effect of our own credit quality on the fair value of our net liability positions with each counterparty. This adjustment takes into account any credit enhancements, such as collateral margin we may have posted with a counterparty, as well as any letters of credit that we have provided. The methodology to determine this adjustment is consistent with how we evaluate counterparty credit risk, taking into account our own credit rating, current credit spreads, as well as any change in such spreads since the last measurement date. • Liquidity valuation adjustments are necessary when we are not able to observe a recent market price for financial instruments that trade in less active markets for the fair value to reflect the cost of exiting the position. Exchange traded contracts are valued at market value without making any additional valuation adjustments and, therefore, no liquidity reserve is applied. For contracts other than exchange traded instruments, we mark our positions to the midpoint of the bid/ask spread, and record a liquidity reserve based upon our total net position. We believe that such practice results in the most reliable fair value measurement as viewed by a market participant. We manage our derivative instruments on a portfolio basis and the valuation adjustments described above are calculated on this basis. We believe that the portfolio level approach represents the highest and best use for these assets as there are benefits inherent in naturally offsetting positions within the portfolio at any given time, and this approach is consistent with how a market participant would view and value the assets and liabilities. Although we take a portfolio approach to managing these assets and liabilities, in order to reflect the fair value of any one individual contract within the portfolio, we allocate all valuation adjustments down to the contract level, to the extent deemed necessary, based upon either the notional contract volume, or the contract value, whichever is more applicable. The methods described above may produce a fair value calculation that may not be indicative of net realizable value or reflective of future fair values. While we believe that our valuation methods are appropriate and consistent with other market participants, we recognize that the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different estimate of fair value at the reporting date. We review our fair value policies on a regular basis taking into consideration changes in the marketplace and, if necessary, will adjust our policies accordingly. See Note 15 - Risk Management and Hedging Activities. Valuation Hierarchy Our fair value measurements are grouped into a three-level valuation hierarchy and are categorized in their entirety in the same level of the fair value hierarchy as the lowest level input that is significant to the entire measurement. The valuation hierarchy is based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date. The three levels are defined as follows. • Level 1 — inputs are unadjusted quoted prices for identical assets or liabilities in active markets. • Level 2 — inputs include quoted prices for similar assets and liabilities in active markets, and inputs that are observable for the asset or liability, either directly or indirectly, for substantially the full term of the financial instrument. • Level 3 — inputs are unobservable and considered significant to the fair value measurement. A financial instrument’s categorization within the hierarchy is based upon the level of judgment involved in the most significant input in the determination of the instrument’s fair value. Following is a description of the valuation methodologies used as well as the general classification of such instruments pursuant to the hierarchy. Commodity Derivative Assets and Liabilities We enter into a variety of derivative financial instruments, which may include exchange traded instruments (such as New York Mercantile Exchange, or NYMEX, crude oil or natural gas futures) or over-the-counter, or OTC, instruments (such as natural gas contracts, crude oil or NGL swaps). The exchange traded instruments are generally executed with a highly rated broker dealer serving as the clearinghouse for individual transactions. Our activities expose us to varying degrees of commodity price risk. To mitigate a portion of this risk and to manage commodity price risk related primarily to owned natural gas storage and pipeline assets, we engage in natural gas asset based trading and marketing, and we may enter into natural gas and crude oil derivatives to lock in a specific margin when market conditions are favorable. A portion of this may be accomplished through the use of exchange traded derivative contracts. Such instruments are generally classified as Level 1 since the value is equal to the quoted market price of the exchange traded instrument as of our balance sheet date, and no adjustments are required. Depending upon market conditions and our strategy we may enter into exchange traded derivative positions with a significant time horizon to maturity. Although such instruments are exchange traded, market prices may only be readily observable for a portion of the duration of the instrument. In order to calculate the fair value of these instruments, readily observable market information is utilized to the extent it is available; however, in the event that readily observable market data is not available, we may interpolate or extrapolate based upon observable data. In instances where we utilize an interpolated or extrapolated value, and it is considered significant to the valuation of the contract as a whole, we would classify the instrument within Level 3. We also engage in the business of trading energy related products and services, which exposes us to market variables and commodity price risk. We may enter into physical contracts or financial instruments with the objective of realizing a positive margin from the purchase and sale of these commodity-based instruments. We may enter into derivative instruments for NGLs or other energy related products, primarily using the OTC derivative instrument markets, which are not as active and liquid as exchange traded instruments. Market quotes for such contracts may only be available for short dated positions (up to six months), and an active market itself may not exist beyond such time horizon. Contracts entered into with a relatively short time horizon for which prices are readily observable in the OTC market are generally classified within Level 2. Contracts with a longer time horizon, for which we internally generate a forward curve to value such instruments, are generally classified within Level 3. The internally generated curve may utilize a variety of assumptions including, but not limited to, data obtained from third-party pricing services, historical and future expected relationship of NGL prices to crude oil prices, the knowledge of expected supply sources coming online, expected weather trends within certain regions of the United States, and the future expected demand for NGLs. Each instrument is assigned to a level within the hierarchy at the end of each financial quarter depending upon the extent to which the valuation inputs are observable. Generally, an instrument will move toward a level within the hierarchy that requires a lower degree of judgment as the time to maturity approaches, and as the markets in which the asset trades will likely become more liquid and prices more readily available in the market, thus reducing the need to rely upon our internally developed assumptions. However, the level of a given instrument may change, in either direction, depending upon market conditions and the availability of market observable data. The following table presents the financial instruments carried at fair value on a recurring basis as of December 31, 2021 and December 31, 2020, by consolidated balance sheet caption and by valuation hierarchy, as described above: December 31, 2021 December 31, 2020 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) Current assets: Commodity derivatives $ 24 $ 62 $ — $ 86 $ 21 $ 42 $ — $ 63 Short-term investments (a) $ 4 $ 1 $ — $ 5 $ — $ — $ — $ — Long-term assets: Commodity derivatives $ — $ 8 $ 2 $ 10 $ 1 $ 13 $ 2 $ 16 Investments in marketable securities (a) $ 28 $ — $ — $ 28 22 $ 1 $ — $ 23 Current liabilities: Commodity derivatives $ (42) $ (100) $ (3) $ (145) $ (19) $ (34) $ (3) $ (56) Long-term liabilities: Commodity derivatives $ (1) $ (25) $ (4) $ (30) $ — $ (6) $ (1) $ (7) (a) $5 million and $4 million recorded within "other" current assets and $28 million and $19 million recorded within "Other long-term assets" as of December 31, 2021 and December 31, 2020, respectively. Changes in Levels 1 and 2 Fair Value Measurements The determination to classify a financial instrument within Level 1 or Level 2 is based upon the availability of quoted prices for identical or similar assets and liabilities in active markets. Depending upon the information readily observable in the market, and/or the use of identical or similar quoted prices, which are significant to the overall valuation, the classification of any individual financial instrument may differ from one measurement date to the next. Changes in Level 3 Fair Value Measurements The tables below illustrate a rollforward of the amounts included in our consolidated balance sheets for derivative financial instruments that we have classified within Level 3. Since financial instruments classified as Level 3 typically include a combination of observable components (that is, components that are actively quoted and can be validated to external sources) and unobservable components, the gains and losses in the table below may include changes in fair value due in part to observable market factors, or changes to our assumptions on the unobservable components. Depending upon the information readily observable in the market, and/or the use of unobservable inputs, which are significant to the overall valuation, the classification of any individual financial instrument may differ from one measurement date to the next. The significant unobservable inputs used in determining fair value include adjustments by other market-based or independently sourced market data such as historical commodity volatilities, crude oil future yield curves, and/or counterparty specific considerations. In the event that there is a movement to/from the classification of an instrument as Level 3, we would reflect such items in the table below within the “Transfers into/out of Level 3” captions. We manage our overall risk at the portfolio level and in the execution of our strategy, we may use a combination of financial instruments, which may be classified within any level. Since Level 1 and Level 2 risk management instruments are not included in the rollforward below, the gains or losses in the table do not reflect the effect of our total risk management activities. Commodity Derivative Instruments Current Long-Term Current Long-Term (millions) Year ended December 31, 2021 (a): Beginning balance $ — $ 2 $ (3) $ (1) Net unrealized losses included in earnings — — (10) (6) Transfers out of Level 3 — — 3 3 Settlements — — 7 — Ending balance $ — $ 2 $ (3) $ (4) Net unrealized gains (losses) on derivatives still held included in earnings $ — $ 1 $ (3) $ (4) Year ended December 31, 2020 (a): Beginning balance $ 4 $ — $ (1) $ (3) Net unrealized (losses) gains included in earnings (1) 5 5 2 Transfers out of Level 3 — (3) — — Settlements (3) — (7) — Ending balance $ — $ 2 $ (3) $ (1) Net unrealized gains (losses) on derivatives still held included in earnings $ — $ 2 $ (3) $ (1) (a) There were no purchases, issuances or sales of derivatives or transfers into Level 3 for the years ended December 31, 2021 and 2020. Quantitative Information and Fair Value Sensitivities Related to Level 3 Unobservable Inputs We utilize the market approach to measure the fair value of our commodity contracts. The significant unobservable inputs used in this approach to fair value are longer dated price quotes. Our sensitivity to these longer dated forward curve prices are presented in the table below. Significant changes in any of those inputs in isolation would result in significantly different fair value measurements, depending on our short or long position in contracts. December 31, 2021 Product Group Fair Value Valuation Techniques Unobservable Input Forward Weighted Average (a) (millions) Assets Natural gas $ 2 Market approach Longer dated forward curve prices $2.22-$3.37 $2.86 Per MMBtu Liabilities NGLs $ (4) Market approach Longer dated forward curve prices $0.30-$1.82 $0.93 Per gallon Natural gas $ (3) Market approach Longer dated forward curve prices $2.17-$3.55 $2.57 Per MMBtu (a) Unobservable inputs were weighted by the instrument's notional amounts. Nonfinancial Assets and Liabilities We utilize fair value to perform impairment tests as required on our property, plant and equipment, goodwill, equity investments in unconsolidated affiliates, and intangible assets. The inputs used to determine such fair value are primarily based upon internally developed cash flow models and would generally be classified within Level 3 in the event that we were required to measure and record such assets at fair value within our consolidated financial statements. Additionally, we use fair value to determine the inception value of our asset retirement obligations. The inputs used to determine such fair value are primarily based upon costs incurred historically for similar work, as well as estimates from independent third parties for costs that would be incurred to restore leased property to the contractually stipulated condition, and would be classified within Level 3. During the year ended December 31, 2021 we determined that a triggering event occurred due to a negative outlook for long-term future throughput volume forecasts for certain assets within the South region of our Gathering and Processing segment and our Logistics and Marketing segment as our expectation for future use of the assets changed. As such, we recognized impairments of long lived assets of $24 million in our consolidated statements of operations. We also recognized a $7 million impairment associated with certain non-core assets held for sale in the Midcontinent region of our Gathering and Processing segment that were sold in July 2021. During the year ended December 31, 2020, we determined that triggering events had occurred with respect to specific asset groups as a result of the impact of commodity prices on the respective recently prepared budget forecasts, coupled with a negative outlook for long-term production volume forecasts for these asset groups. For each of the respective asset groups we determined that the carrying value exceeded the respective undiscounted cash flows. We used the income approach to calculate the fair value of the asset group and compared it to the carrying value. The primary inputs to our calculation were forecasted gathering and processing volumes, future commodity pricing and the discount rate. The impairment amount recorded represented the difference between the fair and carrying values. As a result, we recognized a $587 million impairment loss associated with certain asset groups in the Permian and South regions of our Gathering and Processing segment, including $11 million related to customer contract intangible assets, and an other than temporary impairment of $61 million of our equity investment in Discovery Producer Services LLC (“Discovery”). We may identify additional triggering events requiring future evaluations of the recoverability of the carrying value of our long-lived assets and investments that could result in future impairments. Such impairments could have significant effect on our results of operations, which would be recognized in the period in which the carrying value is determined to be not fully recoverable. The following table presents certain assets and asset groups measured at fair value on a non-recurring basis, by consolidated balance sheet caption as of the date of measurement. Asset Impairments Fair Value 2021 2020 (millions) Long-lived assets $ 1 $ 31 Long-lived assets (a) 96 $ 587 Goodwill — 159 Direct investment in unconsolidated affiliate 256 61 Total $ 31 $ 807 (a) Includes $11 million related to customer contract intangible assets. Estimated Fair Value of Financial Instruments Valuation of a contract’s fair value is validated by an internal group independent of the marketing group. While common industry practices are used to develop valuation techniques, changes in pricing methodologies or the underlying assumptions could result in significantly different fair values and income recognition. When available, quoted market prices or prices obtained through external sources are used to determine a contract’s fair value. For contracts with a delivery location or duration for which quoted market prices are not available, fair value is determined based on pricing models developed primarily from historical and expected relationships with quoted market prices. The fair value of our interest rate swaps, if any, and commodity non-trading derivatives is based on prices supported by quoted market prices and other external sources and prices based on models and other valuation methods. The “prices supported by quoted market prices and other external sources” category includes our interest rate swaps, if any, our NGL and crude oil swaps and our NYMEX positions in natural gas. In addition, this category includes our forward positions in natural gas for which our forward price curves are obtained from a third party pricing service and then validated through an internal process which includes the use of independent broker quotes. This category also includes our forward positions in NGLs at points for which OTC broker quotes for similar assets or liabilities are available for the full term of the instrument. This category also includes “strip” transactions whose pricing inputs are directly or indirectly observable from external sources and then modeled to daily or monthly prices as appropriate. The “prices based on models and other valuation methods” category includes the value of transactions for which inputs to the fair value of the instrument are unobservable in the marketplace and are considered significant to the overall fair value of the instrument. The fair value of these instruments may be based upon an internally developed price curve, which was constructed as a result of the long dated nature of the transaction or the illiquidity of the specific market point. We have determined fair value amounts using available market information and appropriate valuation methodologies. However, considerable judgment is required in interpreting market data to develop the estimates of fair value. Accordingly, the estimates presented herein are not necessarily indicative of the amounts that we could realize in a current market exchange. The use of different market assumptions and/or estimation methods may have a material effect on the estimated fair value amounts. The fair value of accounts receivable and accounts payable are not materially different from their carrying amounts because of the short-term nature of these instruments or the stated rates approximating market rates. Derivative instruments are carried at fair value. We determine the fair value of our fixed-rate senior notes and junior subordinated notes based on quotes obtained from bond dealers. The carrying value of borrowings under the Credit Agreement and the Securitization Facility approximate fair value as their interest rates are based on prevailing market interest rates. We classify the fair values of our outstanding debt balances within Level 2 of the valuation hierarchy. As of December 31, 2021 and December 31, 2020, the carrying value and fair value of our total debt, including current maturities, were as follows: December 31, 2021 December 31, 2020 Carrying Value (a) Fair Value Carrying Value (a) Fair Value (millions) Total debt $ 5,445 $ 6,107 $ 5,635 $ 5,938 (a) Excludes unamortized issuance costs and finance lease liabilities.

Leases (Notes)

Leases (Notes)	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Leases of Lessee Disclosure [Text Block]	Leases We have operating leases for transportation agreements, office space, and field equipment. We have finance leases for field equipment and vehicles. Our leases have remaining lease terms ranging from less than one year to 19 years, some of which may include options to extend leases up to 20 years, and some of which may include options to terminate the leases in less than one year. Extension options on certain compressors and field equipment were included in the lease terms used to calculate our operating lease assets and liabilities as it is reasonably certain that we exercise those options. Operating and finance leases are included on our consolidated balance sheet as follows: Location in Consolidated Balance Sheet As of December 31, 2021 December 31, 2020 (millions) Assets Operating lease assets Operating lease assets $ 104 $ 85 Finance lease assets Property, plant and equipment 28 25 Total right of use assets $ 132 $ 110 Liabilities Current liabilities Operating lease liabilities Other current liabilities $ 26 $ 24 Finance lease liabilities Current debt 5 5 Noncurrent liabilities Operating lease liabilities Operating lease liabilities $ 93 $ 76 Finance lease liabilities Long-term debt 21 22 Total lease liabilities $ 145 $ 127 Variable lease costs primarily consist of common area maintenance on our office spaces and variable transportation costs. The components of lease expense are as follows: Location in Consolidated Statement of Operations Year Ended December 31, 2021 2020 (millions) Operating lease cost Operating and maintenance expense $ 28 $ 27 Finance lease cost Amortization of right of use assets Depreciation and amortization expense 3 2 Interest on lease liabilities Interest expense 1 1 Variable lease cost Operating and maintenance expense 6 6 Short term lease cost Operating and maintenance expense 4 4 Total lease cost $ 42 $ 40 Maturities of operating and finance lease liabilities under non-cancelable leases as of December 31, 2021 are as follows: Future Minimum Lease Payments as of December 31, 2021 Operating Leases Finance Leases (millions) 2022 $ 29 $ 6 2023 28 6 2024 19 7 2025 15 3 2026 9 5 Thereafter 33 5 Total lease payments $ 133 $ 32 Less imputed interest (14) (6) Total lease liabilities $ 119 $ 26 Supplemental cash flow information related to leases is as follows: Year Ended December 31, 2021 2020 (millions) Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 30 $ 27 Operating cash flows from finance leases 5 4 Financing cash flows from finance leases 1 1 Right-of-use assets obtained in exchange for operating lease obligations: $ 44 $ 13 Right-of-use assets obtained in exchange for finance lease obligations: $ 4 $ 5 Other information related to operating leases as follows: Weighted average remaining lease term 6 years 6 years Weighted average discount rate 4.00 % 4.00 % Other information related to finance leases as follows: Weighted average remaining lease term 4 years 5 years Weighted average discount rate 3.00 % 3.00 %

Debt (Notes)

Debt (Notes)	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Debt	Debt December 31, 2021 December 31, 2020 (millions) Senior notes: Issued September 2011, interest at 4.750% payable semi-annually, due September 2021 $ — $ 500 Issued March 2012, interest at 4.950% payable semi-annually, due April 2022 350 350 Issued March 2013, interest at 3.875% payable semi-annually, due March 2023 500 500 Issued July 2018 and January 2019, interest at 5.375% payable semi-annually, due July 2025 825 825 Issued June 2020, interest at 5.625% payable semi-annually, due July 2027 500 500 Issued May 2019, interest at 5.125% payable semi-annually, due May 2029 600 600 Issued August 2000, interest at 8.125% payable semi-annually, due August 2030 (a) 300 300 Issued November 2021, interest at 3.250% payable semi-annually, due February 2032 400 — Issued October 2006, interest at 6.450% payable semi-annually, due November 2036 300 300 Issued September 2007, interest at 6.750% payable semi-annually, due September 2037 450 450 Issued March 2014, interest at 5.600% payable semi-annually, due April 2044 400 400 Junior subordinated notes: Issued May 2013, interest at 5.850% payable semi-annually, due May 2043 550 550 Accounts receivable securitization facility: Accounts receivable securitization facility, interest at 1.000% as of December 31, 2021, due August 2024 260 350 Fair value adjustments related to interest rate swap fair value hedges (a) 16 17 Unamortized issuance costs (38) (38) Unamortized discount, net (6) (7) Finance lease liabilities 26 27 Total debt 5,433 5,624 Current finance lease liabilities 5 5 Current debt 350 500 Total long-term debt $ 5,078 $ 5,119 (a) The swaps associated with this debt were previously terminated. The remaining long-term fair value related to the swaps is being amortized as a reduction to interest expense through 2030, the original maturity date of the debt. Senior Notes Issuance On November 19, 2021, we issued $400 million aggregate principal amount 3.250% Senior Notes due February 2032, unless redeemed prior to maturity. We received proceeds of $396 million, net of underwriters' fees and related expenses, which we used to repay indebtedness under our revolving credit facility and for general partnership purposes. Interest on the notes is payable semi-annually in arrears on February 15 and August 15 of each year, commencing on August 15, 2022. Senior Notes and Junior Subordinated Notes Our senior notes and junior subordinated notes, collectively referred to as our debt securities, mature and become payable on their respective due dates, and are not subject to any sinking fund or mandatory redemption provisions. The senior notes are senior unsecured obligations that are guaranteed by the Partnership and rank equally in a right of payment with our other senior unsecured indebtedness, including indebtedness under our Credit Agreement, and the junior subordinated notes are unsecured and rank subordinate in right of payment to all of our existing and future senior indebtedness. The debt securities include an optional redemption whereby we may elect to redeem the notes, in whole or in part from time-to-time for a premium. Additionally, we may defer the payment of all or part of the interest on the junior subordinated notes for one or more periods up to 5 consecutive years. The underwriters’ fees and related expenses are recorded in our consolidated balance sheets within the carrying amount of long-term debt and will be amortized over the term of the notes. Senior Notes Redemption On June 30, 2021, we repaid, at par, prior to maturity all $500 million aggregate principal amount outstanding of our 4.750% Senior Notes due September 2021 using borrowings under our Revolving Credit Facility. Credit Agreement We are a party to a $1.4 billion unsecured revolving credit facility governed by the Credit Agreement, which matures on December 9, 2024. The Credit Agreement also grants us the option to increase the revolving loan commitment by an aggregate principal amount of up to $500 million, subject to requisite lender approval. The Credit Agreement may be extended for up to two additional one-year periods subject to requisite lender approval. Loans under the Credit Agreement may be used for working capital and other general partnership purposes including acquisitions. The Credit Agreement allows for unrestricted cash and cash equivalents to be netted against consolidated indebtedness for purposes of calculating the Partnership’s Consolidated Leverage Ratio (as defined in the Credit Agreement). Additionally, under the Credit Agreement, the Consolidated Leverage Ratio of the Partnership as of the end of any fiscal quarter shall not exceed 5.00 to 1.0; provided that, if there is a Qualified Acquisition (as defined in the Credit Agreement), the maximum Consolidated Leverage Ratio shall not exceed 5.50 to 1.0 at the end of the three consecutive fiscal quarters, including the fiscal quarter in which the Qualified Acquisition occurs. Our cost of borrowing under the Credit Agreement is determined by a ratings-based pricing grid. Indebtedness under the Credit Agreement bears interest at either: (1) LIBOR, plus an applicable margin of 1.35% based on our current credit rating; or (2) (a) the base rate which shall be the higher of the prime rate, the Federal Funds rate plus 0.50% or the LIBOR Market Index rate plus 1.00%, plus (b) an applicable margin of 0.35% based on our current credit rating. The Credit Agreement incurs an annual facility fee of 0.275% based on our current credit rating. This fee is paid on drawn and undrawn portions of the $1.4 billion revolving credit facility. On December 31, 2021, one-week and two-month U.S. dollar LIBOR settings became permanently unavailable, and all other U.S. dollar LIBOR settings (overnight, one-month, three-month, six-month and 12-month U.S. dollar LIBOR settings) will become permanently unavailable on June 30, 2023. As of December 31, 2021, we had unused borrowing capacity of $1,383 million, net of $17 million of letters of credit, under the Credit Agreement, of which $1,383 million would have been available to borrow for working capital and other general partnership purposes based on the financial covenants set forth in the Credit Agreement. Except in the case of a default, amounts borrowed under our Credit Agreement will not become due prior to the December 9, 2024 maturity date. Accounts Receivable Securitization Facility On August 2, 2021 we entered into an amendment to our Securitization Facility to extend the term of the facility until August 12, 2024 and to provide for an alternative interest rate under the Securitization Facility based on SOFR upon LIBOR becoming unavailable. The amendment also includes Environmental, Social, and Governance linked Key Performance Indicators that increase or decrease certain fees based on our safety performance relative to our peers, and year-over-year change in our greenhouse gas emissions intensity rate. The Securitization Facility provides for up to $350 million of borrowing capacity through August 2024 at LIBOR market index rates plus a margin. Such interest rates will change as described above upon LIBOR becoming unavailable. Under this Securitization Facility, certain of the Partnership’s wholly owned subsidiaries sell or contribute receivables to another of the Partnership’s consolidated subsidiaries, DCP Receivables LLC (“DCP Receivables”), a bankruptcy-remote special purpose entity created for the sole purpose of the Securitization Facility. DCP Receivables’ sole activity consists of purchasing receivables from the Partnership’s wholly owned subsidiaries that participate in the Securitization Facility and providing these receivables as collateral for DCP Receivables’ borrowings under the Securitization Facility. DCP Receivables is a separate legal entity and the accounts receivable of DCP Receivables, up to the amount of the outstanding debt under the Securitization Facility, are not available to satisfy the claims of creditors of the Partnership, its subsidiaries selling receivables under the Securitization Facility, or their affiliates. Any excess receivables are eligible to satisfy the claims of creditors of the Partnership, its subsidiaries selling receivables under the Securitization Facility, or their affiliates. The amount available for borrowing may be limited by the availability of eligible receivables and other customary factors and conditions, as well as the covenants set forth in the Securitization Facility. As of December 31, 2021, DCP Receivables had approximately $1,175 of our accounts receivable securing borrowings of $260 million under the Securitization Facility. The maturities of our debt as of December 31, 2021 are as follows: Debt (millions) 2022 $ 350 2023 500 2024 260 2025 825 2026 — Thereafter 3,500 Total debt $ 5,435

Risk Management and Hedging Act

Risk Management and Hedging Activities (Notes)	12 Months Ended
	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Risk Management and Hedging Activities	Risk Management and Hedging Activities Our operations expose us to a variety of risks including but not limited to changes in the prices of commodities that we buy or sell, changes in interest rates, and the creditworthiness of each of our counterparties. We manage certain of these exposures with either physical or financial transactions. We have established a comprehensive risk management policy and a risk management committee (the “Risk Management Committee”), to monitor and manage market risks associated with commodity prices and counterparty credit. The Risk Management Committee is composed of senior executives who receive regular briefings on positions and exposures, credit exposures and overall risk management in the context of market activities. The Risk Management Committee is responsible for the overall management of credit risk and commodity price risk, including monitoring exposure limits. Commodity Price Risk Our portfolio of commodity derivative activity is primarily accounted for using the mark-to-market method of accounting; however, depending upon our risk profile and objectives, in certain limited cases, we may execute transactions that qualify for the hedge method of accounting. The risks, strategies and instruments used to mitigate such risks, as well as the method of accounting are discussed and summarized below. Natural Gas Asset Based Trading and Marketing Our natural gas storage and pipeline assets are exposed to certain risks including changes in commodity prices. We manage commodity price risk related to our natural gas storage and pipeline assets through our commodity derivative program. The commercial activities related to our natural gas storage and pipeline assets primarily consist of the purchase and sale of gas and associated time spreads and basis spreads. A time spread transaction is executed by establishing a long gas position at one point in time and establishing an equal short gas position at a different point in time. Time spread transactions allow us to lock in a margin supported by the injection, withdrawal, and storage capacity of our natural gas storage assets. We may execute basis spread transactions to mitigate the risk of sale and purchase price differentials across our system. A basis spread transaction allows us to lock in a margin on our physical purchases and sales of gas, including injections and withdrawals from storage. We typically use swaps to execute these transactions, which are not designated as hedging instruments and are recorded at fair value with changes in fair value recorded in the current period consolidated statements of operations. While gas held in our storage locations is recorded at the lower of average cost or market, the derivative instruments that are used to manage our storage facilities are recorded at fair value and any changes in fair value are currently recorded in our consolidated statements of operations. Even though we may have economically hedged our exposure and locked in a future margin, the use of lower-of-cost or net realizable value for our physical inventory and the use of mark-to-market accounting for our derivative instruments may subject our earnings to market volatility. Commodity Cash Flow Hedges In order for our natural gas storage facility to remain operational, a minimum level of base gas must be maintained in each storage cavern, which is capitalized on our consolidated balance sheets as a component of property, plant and equipment, net. During construction or expansion of our storage caverns, we may execute a series of derivative financial instruments to mitigate a portion of the risk associated with the forecasted purchase of natural gas when we bring the storage caverns into operation. These derivative financial instruments may be designated as cash flow hedges. While the cash paid upon settlement of these hedges economically fixes the cash required to purchase base gas, the deferred losses or gains would remain in accumulated other comprehensive income (AOCI), until the cavern is emptied and the base gas is sold. The balance in AOCI of our previously settled base gas cash flow hedges was in a loss position of $6 million as of December 31, 2021. Commodity Cash Flow Protection Activities We are exposed to the impact of market fluctuations in the prices of natural gas, NGLs and condensate as a result of our gathering, processing, sales and storage activities. For gathering, processing and storage services, we may receive cash or commodities as payment for these services, depending on the contract type. We may enter into derivative financial instruments to mitigate a portion of the risk of weakening natural gas, NGL and condensate prices associated with our gathering, processing and sales activities, thereby stabilizing our cash flows. As of December 31, 2021 our derivative financial instruments used to mitigate a portion of the risk of weakening natural gas, NGL and condensate prices extend through the end of 2023. The commodity derivative instruments used for our hedging programs are a combination of direct NGL product, crude oil and natural gas hedges. Crude oil and NGL transactions are primarily accomplished through the use of forward contracts that effectively exchange floating price risk for a fixed price. The type of instrument used to mitigate a portion of the risk may vary depending on our risk management objectives. These transactions are not designated as hedging instruments for accounting purposes and the change in fair value is reflected in the current period within our consolidated statements of operations as trading and marketing gains and (losses), net. NGL Proprietary Trading Our NGL proprietary trading activity includes trading energy related products and services. We undertake these activities through the use of fixed forward sales and purchases, basis and spread trades, storage opportunities, put/call options, term contracts and spot market trading. These energy trading operations are exposed to market variables and commodity price risk with respect to these products and services, and these operations may enter into physical contracts and financial instruments with the objective of realizing a positive margin from the purchase and sale of commodity-based instruments. These physical and financial instruments are not designated as hedging instruments and are recorded at fair value with changes in fair value recorded in the current period consolidated statements of operations. We employ established risk limits, policies and procedures to manage risks associated with our natural gas asset based trading and marketing and NGL proprietary trading. Credit Risk Our principal customers range from large, natural gas marketers to industrial end-users for our natural gas products and services, as well as large multi-national petrochemical and refining companies, to small regional propane distributors for our NGL products and services. Substantially all of our natural gas and NGL sales are made at market-based prices. This concentration of credit risk may affect our overall credit risk, in that these customers may be similarly affected by changes in economic, regulatory or other factors. Where exposed to credit risk, we analyze the counterparties’ financial condition prior to entering into an agreement, establish credit limits and monitor the appropriateness of these limits on an ongoing basis. We may use various master agreements that include language giving us the right to request collateral to mitigate credit exposure. The collateral language provides for a counterparty to po st cash or letters of credit for exposure in excess of the established threshold. The threshold amount represents an open credit limit, determined in accordance with o ur credit policy. The collateral language also provides that the inability to post collateral is sufficient cause to terminate a contract and liquidate all positions. In addition, our master agreements and our standard gas and NGL sales contracts contain adequate assurance provisions, which allow us to suspend deliveries and cancel agreements, or continue deliveries to the buyer after the buyer provides acceptable security for payment. Contingent Credit Features Each of the above risks is managed through the execution of individual contracts with a variety of counterparties. Certain of our derivative contracts may contain credit-risk related contingent provisions that may require us to take certain actions in certain circumstances. We have International Swaps and Derivatives Association, or ISDA, contracts which are standardized master legal arrangements that establish key terms and conditions which govern certain derivative transactions. These ISDA contracts contain standard credit-risk related contingent provisions. Some of the provisions we are subject to are outlined below. • If we were to have an effective event of default under our Credit Agreement that occurs and is continuing, our ISDA counterparties may have the right to request early termination and net settlement of any outstanding derivative liability positions. • Our ISDA counterparties generally have collateral thresholds of zero, requiring us to fully collateralize any commodity contracts in a net liability position, when our credit rating is below investment grade. • Additionally, in some cases, our ISDA contracts contain cross-default provisions that could constitute a credit-risk related contingent feature. These provisions apply if we default in making timely payments under other credit arrangements and the amount of the default is above certain predefined thresholds, which are significantly high and are generally consistent with the terms of our Credit Agreement. As of December 31, 2021, we were not a party to any agreements that would trigger the cross-default provisions. Our commodity derivative contracts that are not governed by ISDA contracts do not have any credit-risk related contingent features. Depending upon the movement of commodity prices and interest rates, each of our individual contracts with counterparties to our commodity derivative instruments or interest rate swap instruments are in either a net asset or net liability position. As of December 31, 2021, we had $5 million of individual commodity derivative contracts that contain credit-risk related contingent features that were in a net liability position. If we were required to net settle our position with an individual counterparty, due to a credit-risk related event, our ISDA contracts may permit us to net all outstanding contracts with that counterparty, whether in a net asset or net liability position, as well as any cash collateral already posted. As of December 31, 2021, we have not been required to post additional collateral. Although our commodity derivative contracts that contain credit-risk related contingent features were in a net liability position as of December 31, 2021, the net liability position would be offset by contracts in a net asset position reducing our net liability to $2 million. Collateral As of December 31, 2021, we had cash deposits of $128 million, included in collateral cash deposits in our consolidated balance sheets. Additionally, as of December 31, 2021, we held letters of credit of $131 million from counterparties to secure their future performance under financial or physical contracts. Collateral amounts held or posted may be fixed or may vary, depending on the value of the underlying contracts, and could cover normal purchases and sales, services, trading and hedging contracts. In many cases, we and our counterparties have publicly disclosed credit ratings, which may impact the amounts of collateral requirements. Physical forward contracts and financial derivatives are cash settled at the expiration of the contract term. These transactions are generally subject to specific credit provisions within the contracts that would allow the seller, at its discretion, to suspend deliveries, cancel agreements or continue deliveries to the buyer after the buyer provides security for payment satisfactory to the seller. Offsetting Certain of our financial derivative instruments are subject to a master netting or similar arrangement, whereby we may elect to settle multiple positions with an individual counterparty through a single net payment. Each of our individual derivative instruments are presented on a gross basis on the consolidated balance sheets, regardless of our ability to net settle our positions. Instruments that are governed by agreements that include net settle provisions allow final settlement, when presented with a termination event, of outstanding amounts by extinguishing the mutual debts owed between the parties in exchange for a net amount due. We have trade receivables and payables associated with derivative instruments, subject to master netting or similar agreements, which are not included in the table below. The following summarizes the gross and net amounts of our derivative instruments: December 31, 2021 December 31, 2020 Gross Amounts Amounts Not Net Gross Amounts Amounts Not Net (millions) Assets: Commodity derivatives $ 96 $ — $ 96 $ 79 $ — $ 79 Liabilities: Commodity derivatives $ (175) $ — $ (175) $ (63) $ — $ (63) Summarized Derivative Information The fair value of our derivative instruments that are marked-to-market each period, as well as the location of each within our consolidated balance sheets, by major category, is summarized below. We have no derivative instruments that are designated as hedging instruments for accounting purposes as of December 31, 2021 and December 31, 2020. Balance Sheet Line Item December 31, December 31, Balance Sheet Line Item December 31, December 31, (millions) (millions) Derivative Assets Not Designated as Hedging Instruments: Derivative Liabilities Not Designated as Hedging Instruments: Commodity derivatives: Commodity derivatives: Unrealized gains on derivative instruments — current $ 86 $ 63 Unrealized losses on derivative instruments — current $ (145) $ (56) Unrealized gains on derivative instruments — long-term 10 16 Unrealized losses on derivative instruments — long-term (30) (7) Total $ 96 $ 79 Total $ (175) $ (63) The following summarizes the balance and activity within AOCI relative to our interest rate, commodity and foreign currency cash flow hedges as of and for the year ended December 31, 2021: Interest Commodity Foreign Total (millions) Net deferred (losses) gains in AOCI (beginning balance) $ (2) $ (6) $ 1 $ (7) Losses reclassified from AOCI to earnings — effective portion 1 — — 1 Net deferred (losses) gains in AOCI (ending balance) $ (1) $ (6) $ 1 $ (6) Deferred losses in AOCI expected to be reclassified into earnings over the next 12 months $ — $ — $ — $ — (a) Relates to Discovery, an unconsolidated affiliate. The following summarizes the balance and activity within AOCI relative to our interest rate, commodity and foreign currency cash flow hedges as of and for the year ended December 31, 2020: Interest Commodity Foreign Total (millions) Net deferred (losses) gains in AOCI (beginning balance) $ (2) $ (6) $ 1 $ (7) Net deferred (losses) gains in AOCI (ending balance) $ (2) $ (6) $ 1 $ (7) Deferred losses in AOCI expected to be reclassified into earnings over the next 12 months $ — $ — $ — $ — (a) Relates to Discovery, an unconsolidated affiliate. For the years ended December 31, 2021 and 2020, no derivative losses attributable to the ineffective portion or to amounts excluded from effectiveness testing were recognized in trading and marketing gains or losses, net or interest expense in our consolidated statements of operations. For the years ended December 31, 2021 and 2020, no derivative losses were reclassified from AOCI to trading and marketing gains or losses, net or interest expense as a result of the discontinuance of cash flow hedges related to certain forecasted transactions that are not probable of occurring. Changes in the value of derivative instruments, for which the hedge method of accounting has not been elected from one period to the next, are recorded in the consolidated statements of operations. The following summarizes these amounts and the location within the consolidated statements of operations that such amounts are reflected: Commodity Derivatives: Statements of Operations Line Item Year Ended December 31, 2021 2020 2019 (millions) Realized (losses) gains $ (493) $ 101 $ 65 Unrealized (losses) gains (125) 55 (78) Trading and marketing (losses) gains, net $ (618) $ 156 $ (13) We do not have any derivative financial instruments that are designated as a hedge of a net investment. The following tables represent, by commodity type, our net long or short positions that are expected to partially or entirely settle in each respective year. To the extent that we have long dated derivative positions that span multiple calendar years, the contract will appear in more than one line item in the tables below. December 31, 2021 Crude Oil Natural Gas Natural Gas Natural Gas Year of Expiration Net Short Net (Short) Long Position Net Short Net (Short) Long 2022 (1,133,000) (76,565,200) (5,080,635) (7,015,000) 2023 (446,000) 912,500 (1,344,000) (830,000) 2024 — — (1,455,000) (2,280,000) 2025 — — (1,440,000) 9,530,000 2026 — — (1,440,000) 535,000 December 31, 2020 Crude Oil Natural Gas Natural Gas Natural Gas Year of Expiration Net Short Net Short Position Net Short Net Long (Short) 2021 (1,969,000) (69,887,800) (9,857,339) (7,130,000) 2022 (214,000) (36,500,000) (1,422,842) 10,950,000 2023 — — (1,440,000) 3,650,000 2024 — — (1,440,000) 2,140,000 2025 — — (1,320,000) 1,825,000

Partnership Equity and Distribu

Partnership Equity and Distributions (Notes)	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Partnership Equity and Distributions	Partnership Equity and Distributions Preferred Units — The Preferred Units rank senior to our common units with respect to distribution rights and rights upon liquidation. Holders of the Preferred Units have no voting rights except for certain limited protective voting rights set forth in our Partnership Agreement. Distributions of the Preferred Units are payable out of available cash, are accretive and are cumulative from the date of original issuance of the Preferred Units. • Distributions on the Series A Preferred Units are payable semiannually in arrears on June 15th and December 15th of each year. • Distributions on the Series B Preferred Units are payable quarterly in arrears on the 15th day of March, June, September and December of each year to holders of record as of the close of business on the first business day of the month in which the distribution will be made. • Distributions on the Series C Preferred Units are payable quarterly in arrears on the 15th day of January, April, July and October of each year to holders of record as of the close of business on the first business day of the month in which the distribution will be made. Common Units — During the years ended December 31, 2021 and 2020, we issued no common units pursuant to our at-the-market program. As of December 31, 2021, $750 million of common units remained available for sale pursuant to our at-the-market program. Our general partner is entitled to a percentage of all quarterly distributions equal to its limited partner interest, together with DCP Midstream, LLC, of approximately 57% as of December 31, 2021. Definition of Available Cash — Our Partnership Agreement requires that, within 45 days after the end of each quarter, we distribute all of our available cash, as defined in the Partnership Agreement, to unitholders of record on the applicable record date, as determined by our general partner. Available cash, for any quarter, consists of all cash and cash equivalents on hand at the end of that quarter: • less the amount of cash reserves established by our general partner to: • provide for the proper conduct of our business, including reserves for future capital expenditures and anticipated credit needs; • comply with applicable law or any debt instrument or other agreement or obligation; • provide funds to make payments on the Preferred Units; or • provide funds for distributions to our common unitholders for any one or more of the next four quarters. • plus, if our general partner so determines, all or a portion of cash and cash equivalents on hand on the date of determination of available cash for the quarter. Distributions — The following table presents our cash distributions paid in 2021, 2020, and 2019: Payment Date Per Unit Total Cash (millions) Distributions to common unitholders November 12, 2021 $ 0.39 $ 81 August 13, 2021 $ 0.39 $ 81 May 14, 2021 $ 0.39 $ 82 February 12, 2021 $ 0.39 $ 81 November 13, 2020 $ 0.39 $ 81 August 14, 2020 $ 0.39 $ 82 May 15, 2020 $ 0.39 $ 81 February 14, 2020 $ 0.78 $ 162 November 14, 2019 $ 0.78 $ 155 August 14, 2019 $ 0.78 $ 154 May 15, 2019 $ 0.78 $ 155 February 14, 2019 $ 0.78 $ 154 Distributions to Series A Preferred unitholders December 15, 2021 $ 36.8750 $ 19 June 15, 2021 $ 36.8750 $ 18 December 15, 2020 $ 36.8750 $ 19 June 15, 2020 $ 36.8750 $ 18 December 16, 2019 $ 36.8750 $ 19 June 17, 2019 $ 36.8750 $ 18 Distributions to Series B Preferred unitholders December 15, 2021 $ 0.4922 $ 3 September 15, 2021 $ 0.4922 $ 4 June 15, 2021 $ 0.4922 $ 3 March 15, 2021 $ 0.4922 $ 3 December 15, 2020 $ 0.4922 $ 4 September 15, 2020 $ 0.4922 $ 3 June 15, 2020 $ 0.4922 $ 3 March 16, 2020 $ 0.4922 $ 3 December 16, 2019 $ 0.4922 $ 4 September 16, 2019 $ 0.4922 $ 3 June 17, 2019 $ 0.4922 $ 3 March 15, 2019 $ 0.4922 $ 3 Distributions to Series C Preferred unitholders October 15, 2021 $ 0.4969 $ 3 July 15, 2021 $ 0.4969 $ 2 April 15, 2021 $ 0.4969 $ 2 January 15, 2021 $ 0.4969 $ 2 October 15, 2020 $ 0.4969 $ 2 July 15, 2020 $ 0.4969 $ 3 April 15, 2020 $ 0.4969 $ 2 January 15, 2020 $ 0.4969 $ 2 October 15, 2019 $ 0.4969 $ 2 July 15, 2019 $ 0.4969 $ 3 April 15, 2019 $ 0.4969 $ 2 January 15, 2019 $ 0.5576 $ 2

Equity-Based Compensation (Note

Equity-Based Compensation (Notes)	12 Months Ended
	Dec. 31, 2020
Share-based Payment Arrangement [Abstract]
Equity-Based Compensation	Equity-Based Compensation On April 28, 2016, the unitholders of the Partnership approved the 2016 Long-Term Incentive Plan (the “2016 LTIP” or, the “LTIP”). The 2016 plan authorizes up to 900,000 common units to be available for issuance under awards to employees, officers, and non-employee directors of the General Partner and its affiliates. Awards under the 2016 LTIP may include unit options, phantom units, restricted units, distribution equivalent rights ("DERs"), unit bonuses, common unit awards, and performance awards. The 2016 LTIP will expire on the earlier of the date it is terminated by the board of directors of the General Partner or the date that all common units available under the plan have been paid or issued. Under DCP Midstream, LLC's Long-Term Incentive Plan ("DCP Midstream LTIP"), awards may be granted to key employees. The DCP Midstream LTIP provides for the grant of Strategic Performance Units ("SPUs") and Phantom Units. The SPUs and Phantom Units consist of a notional unit based on the fair market value of a common unit of the Partnership. Since we have the intent and ability to settle certain awards within our control in units, we classify them as equity awards based on their fair value. The fair value of our equity awards is determined based on the closing price of our common units on the grant date. Compensation expense on equity awards is recognized ratably over each vesting period. We account for other awards which are subject to settlement in cash, including DERs, as liability awards. Compensation expense on these awards is recognized ratably over each vesting period, and will be re-measured each reporting period for all awards outstanding until the units are vested. The fair value of all liability awards is determined based on the closing price of our common units at each measurement date. Phantom Units issued in 2020 and thereafter are designed to pay out proportionally in cash and DCP Common LP Units. Equity-based compensation expense was $20 million, $11 million and $14 million for the years ended December 31, 2021, 2020 and 2019, respectively. The following table presents the fair value of unvested unit-based awards related to the SPUs and Phantom Units: Vesting Period (years) Unrecognized Estimated Weighted-Average Remaining Vesting DCP Midstream LTIP: SPUs 3 $ 7 0% - 11% 2 Phantom Units 1 - 3 $ 7 0% - 11% 1 Strategic Performance Units - The number of SPUs that will ultimately vest range in value of up to 200% of the outstanding SPUs, depending on the achievement of specified performance targets over a three year period. The final performance payout is determined by the compensation committee of our General Partner. SPU awards include the right to receive DERs, during the performance period or vesting period, as applicable, based on the number of units granted. The DERs are paid in cash at the end of the performance period. The following table presents information related to SPUs: Units Grant Date Weighted-Average Price Per Unit Measurement Date Weighted-Average Price Per Unit Outstanding at January 1, 2019 251,319 $ 43.33 Granted 222,440 $ 30.60 Forfeited (40,348) $ 34.95 Vested (a) (83,054) $ 56.80 Outstanding at December 31, 2019 350,357 $ 33.02 Granted 296,700 $ 23.71 Forfeited (76,183) $ 27.45 Vested (b) (141,613) $ 36.23 Outstanding at December 31, 2020 429,261 $ 26.52 Granted 323,460 $ 19.44 Forfeited (54,641) $ 21.32 Vested (c) (173,171) $ 30.60 Outstanding at December 31, 2021 524,909 $ 21.35 $ 27.48 Expected to vest 481,926 $ 21.35 27.48 (a) The 2017 grants vested at 120%. (b) The 2018 grants vested at 152%. (c) The 2019 grants vested at 150% The estimate of SPUs that are expected to vest is based on highly subjective assumptions that could change over time, including the expected forfeiture rate and achievement of performance targets. The following table presents the fair value of units vested and the unit-based liabilities paid for unit-based awards related to the strategic performance units: Units Fair Value of Units Vested Unit-Based Liabilities Paid (millions) Vested or paid in cash in 2019 83,054 $ 6 $ 9 Vested or paid in cash in 2020 141,613 $ 4 $ 6 Vested or paid in cash in 2021 173,171 $ 7 $ 4 Phantom Units - Phantom Units generally cliff vest at the end of three years and include the right to receive DERs, during the vesting period, as applicable, based on the number of units granted. The DERs are paid quarterly in arrears. Phantom Units may be settled by issuing units or in cash payments equal to the fair value of the awards, which is based on the market prices of our stock near the end of the performance periods. The following table presents information related to Phantom Units: Units Grant Date Weighted-Average Price Per Unit Measurement Date Weighted-Average Price Per Unit Outstanding at January 1, 2019 231,706 $ 42.55 Granted 281,930 $ 30.52 Forfeited (43,170) $ 34.14 Vested (171,881) $ 40.92 Outstanding at December 31, 2019 298,585 $ 33.35 Granted 671,040 $ 20.07 Forfeited (78,320) $ 22.99 Vested (123,817) $ 36.25 Outstanding at December 31, 2020 767,488 $ 22.33 Granted 403,130 $ 21.64 Forfeited (221,480) $ 20.43 Vested (362,116) $ 24.88 Outstanding at December 31, 2021 587,022 $ 20.99 $ 22.80 Expected to vest 523,046 $ 20.98 $ 22.80 The following table presents the fair value of units vested and the unit-based liabilities paid for unit based awards related to the phantom units: Units Fair Value of Units Vested Unit-Based Liabilities Paid (millions) Vested or paid in cash in 2019 171,881 $ 6 $ 5 Vested or paid in cash in 2020 123,817 $ 3 $ 6 Vested or paid in cash in 2021 362,116 $ 5 $ 3

Benefits

Benefits	12 Months Ended
	Dec. 31, 2021
Retirement Benefits [Abstract]
Compensation and Employee Benefit Plans [Text Block]	BenefitsWe do not have our own employees. The employees supporting our operations are employees of DCP Services, LLC, for which we incur charges under the Services Agreement. All DCP Services, LLC employees who have reached the age of 18 and work at least 20 hours per week are eligible for participation in the 401(k) and retirement plan, to which a range of 4% to 7% of each eligible employee’s qualified earnings is contributed to the retirement plan, based on years of service. All new employees are automatically enrolled in the 401(k) plan at a 6% contribution level. Employees can opt out of this contribution level or change it at any time. Additionally, DCP Services, LLC matches employees’ contributions in the 401(k) plan up to 6% of qualified earnings. During the years ended December 31, 2021, 2020 and 2019, we expensed plan contributions of $24 million, $26 million and $31 million, respectively. DCP Services, LLC offers certain eligible executives the opportunity to participate in the Executive Deferred Compensation ("EDC") Plan. The EDC Plan allows participants to defer current compensation on a pre-tax basis and to receive tax deferred earnings on such contributions. The EDC Plan also has make-whole provisions for plan participants who may otherwise be limited in the amount that we can contribute to the 401(k) plan on the participant’s behalf.

Net Income or Loss per Limited

Net Income or Loss per Limited Partner Unit (Notes)	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
Net Income or Loss per Limited Partner Unit	Net Income or Loss per Limited Partner Unit We have the ability to elect to settle restricted phantom units at our discretion in either cash or common units. For restricted phantom units granted during 2021 and 2020, we have the ability and intent to settle vested units through the issuance of common units. There were 304,270 restricted phantom units outstanding as of December 31, 2020 that were not included in the calculation of diluted net loss per unit for the year ended December 31, 2020 because including them would have been anti-dilutive. Basic and diluted net income per limited partner unit was calculated as follows for the years indicated: Year Ended December 31, 2021 2020 2019 (millions, except per unit amounts) Net income (loss) attributable to limited partners $ 332 $ (365) $ (160) Weighted average limited partner units outstanding, basic 208,366,254 208,338,544 153,116,233 Dilutive effects of nonvested restricted phantom units 233,804 — — Weighted average limited partner units outstanding, diluted 208,600,058 208,338,544 153,116,233 Net income (loss) per limited partner unit, basic and diluted $ 1.59 $ (1.75) $ (1.05)

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes We are structured as a master limited partnership with sufficient qualifying income, which is a pass-through entity for federal income tax purposes. Income tax expense consists of the following: Year Ended December 31, 2021 2020 2019 (millions) Current: State income tax expense $ (1) $ — $ (1) Deferred: State income tax (expense) benefit (5) — 2 Total income tax (expense) benefit $ (6) $ — $ 1 As of December 31, 2021 and 2020, we had state deferred tax liabilities of $34 million and $30 million, respectively. The state deferred tax liabilities are primarily associated with Texas franchise taxes. Our effective tax rate differs from statutory rates, primarily due to being structured as a master limited partnership, which is a pass-through entity for federal income tax purposes, while being treated as a taxable entity in certain states, primarily Texas. The State of Texas imposes a margin tax that is assessed at 0.75%, of taxable margin apportioned to Texas for each year ended December 31, 2021, 2020 and 2019.

Commitments and Contingent Liab

Commitments and Contingent Liabilities (Notes)	12 Months Ended
	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingent Liabilities	Commitments and Contingent Liabilities Litigation — We are not a party to any material legal proceedings, but are a party to various administrative and regulatory proceedings and commercial disputes that have arisen in the ordinary course of our business. Management currently believes that the ultimate resolution of the foregoing matters, taken as a whole, and after consideration of amounts accrued, insurance coverage or other indemnification arrangements, will not have a material adverse effect on our results of operations, financial position, or cash flow. Insurance — Our insurance coverage is carried with third-party insurers and with an affiliate of Phillips 66. Our insurance coverage includes: (i) general liability insurance covering third-party exposures; (ii) statutory workers’ compensation insurance; (iii) automobile liability insurance for all owned, non-owned and hired vehicles; (iv) excess liability insurance above the established primary limits for general liability and automobile liability insurance; (v) property insurance, which covers the replacement value of real and personal property and includes business interruption; and (vi) insurance covering our directors and officers for acts related to our business activities. All coverage is subject to certain limits and deductibles, the terms and conditions of which are common for companies with similar types of operations. Environment, Health and Safety — The operation of pipelines, plants and other facilities for gathering, transporting, processing, treating, fractionating, or storing natural gas, NGLs and other products is subject to stringent and complex laws and regulations pertaining to the environment, health and safety. As an owner or operator of these facilities, we must comply with laws and regulations at the federal, state and, in some cases, local levels that relate to worker health and safety, public health and safety, pipeline safety, air and water quality, solid and hazardous waste management and disposal, and other environmental matters. The cost of planning, designing, constructing and operating pipelines, plants, and other facilities incorporates compliance with environmental laws and regulations, health and safety standards applicable to workers and the public, and safety standards applicable to our various facilities. In addition, there is increasing focus from (i) regulatory bodies and communities, and through litigation, on hydraulic fracturing and the real or perceived environmental or public health impacts of this technique, which indirectly presents some risk to our available supply of natural gas and the resulting supply of NGLs; (ii) regulatory bodies regarding pipeline system safety which could impose additional regulatory burdens and increase the cost of our operations; (iii) state and federal regulatory officials regarding the emission of greenhouse gases and other air emissions associated with our operations or the materials managed as part of our business, which could impose regulatory burdens and increase the cost of our operations; and (iv) regulatory bodies and communities that could prevent or delay the development of fossil fuel energy infrastructure such as pipelines, plants, and other facilities used in our business. Failure to comply with these various health, safety and environmental laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures, including citizen suits, which can include the assessment of monetary penalties, the imposition of remedial requirements, and the issuance of injunctions or restrictions on operation. Management believes that, based on currently known information, compliance with these existing laws and regulations will not have a material adverse effect on our results of operations, financial position or cash flows. The following pending proceedings involve governmental authorities as a party under federal, state, and local laws regulating the discharge of materials into the environment. We have elected to disclose matters where we reasonably believe such proceeding would result in monetary sanctions, exclusive of interest and costs, of $1.0 million or more. It is not possible for us to predict the final outcome of these pending proceedings; however, we do not expect the outcome of one or more of these proceedings to have a material adverse effect on our results of operations, financial position, or cash flows: • In March 2019, Region 8 of the U.S. Environmental Protection Agency (“EPA”) issued a Notice of Violation alleging various non-compliance with federal Leak Detection and Repair regulations, known as Subparts KKK and OOOO that exist to mitigate emissions of volatile organic compounds from certain equipment at natural gas plants, at various times over the course of late 2011 through 2017 at five of our Colorado natural gas processing plants. DCP does not agree with many of the allegations of non-compliance. DCP has been and is engaging in information exchanges and discussions with EPA about the propriety of the allegations, including the facts and regulatory underpinnings of the various allegations. DCP’s recent discussions with EPA include the possibility of resolving the allegations, including potential civil penalties and other elements, although this matter may end up in formal proceedings. EPA may require a civil penalty or equivalent that is larger than the disclosure threshold amount described above, although we do not believe that the result of this matter would have a material adverse effect on our results of operations, financial position, or cash flows. • In 2018, the Colorado Department of Public Health and Environment (“CDPHE”) issued a Compliance Advisory in relation to an improperly permitted facility flare and related air emissions from flare operations at one of our gas processing plants, which we had self-disclosed to CDPHE in December 2017. Following information exchanges and discussions with CDPHE, a resolution was proposed pursuant to which the plant's air permit would be revised to include the flare and emissions limits for such flare in addition to us paying an administrative penalty as well as an economic benefit payment generally covering the period when the flare was required to be included in the facility air permit. A revised air permit was issued in May 2019, but the parties had not yet entered into a final settlement agreement to complete the matter. Subsequently, in July 2020 CDPHE issued a Notice of Violation in relation to amine treater emissions at this gas processing plant, which we had self-disclosed to CDPHE in April 2020. We are still exchanging information and holding discussions with CDPHE as to this and the foregoing flare-related enforcement matter, including possible settlement terms, although these matters, which have since been combined, may end up in formal legal proceedings. It is possible that resolution of this matter may include an administrative penalty and economic benefit payment, further revising the facility air permit, or installation of emissions management equipment, or a combination of these, that could, in the aggregate, exceed the disclosure threshold amount described above, although we do not believe that resolution of this matter would have a material adverse effect on our results of operations, financial position, or cash flows.

Restructuring (Notes)

Restructuring (Notes)	12 Months Ended
	Dec. 31, 2021
Restructuring and Related Activities [Abstract]
Restructuring and Related Activities Disclosure [Text Block]	Restructuring CostsIn April 2020, we announced a reduction in force of 15%, which resulted in $9 million of nonrecurring expense for the year ended December 31, 2020.

Business Segments (Notes)

Business Segments (Notes)	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Business Segments	Business Segments Our operations are organized into two reportable segments: (i) Logistics and Marketing and (ii) Gathering and Processing. These segments are monitored separately by management for performance against our internal forecast and are consistent with internal financial reporting. These segments have been identified based on the differing products and services, regulatory environment and the expertise required for these operations. Our Gathering and Processing reportable segment includes operating segments that have been aggregated based on the nature of the products and services provided. Adjusted gross margin is a performance measure utilized by management to monitor the operations of each segment. The accounting policies of the reportable segments are the same as those described in the summary of significant accounting policies included in Note 2 . Our Logistics and Marketing segment includes transporting, trading, marketing, storing natural gas and NGLs, and fractionating NGLs. Our Gathering and Processing segment consists of gathering, compressing, treating, processing natural gas, producing and fractionating NGLs, and recovering condensate. The remainder of our business operations is presented as “Other,” and consists of unallocated corporate costs. Elimination of inter-segment transactions are reflected in the Eliminations column. The following tables set forth our segment information: Year Ended December 31, 2021 Logistics and Marketing Gathering and Processing Other Eliminations Total (millions) Total operating revenue $ 9,734 $ 6,894 $ — $ (5,921) $ 10,707 Adjusted gross margin (a) $ 138 $ 1,304 $ — $ — $ 1,442 Operating and maintenance expense (38) (603) (18) — (659) General and administrative expense (6) (15) (202) — (223) Depreciation and amortization expense (12) (325) (27) — (364) Asset impairments (13) (18) — — (31) Other income (expense), net 6 (1) — — 5 Gain (loss) on sale of assets, net 2 (7) — — (5) Earnings from unconsolidated affiliates 519 16 — — 535 Interest expense — — (299) — (299) Income tax expense — — (6) — (6) Net income (loss) $ 596 $ 351 $ (552) $ — $ 395 Net income attributable to noncontrolling interests — (4) — — (4) Net income (loss) attributable to partners $ 596 $ 347 $ (552) $ — $ 391 Non-cash derivative mark-to-market $ (19) $ (106) $ — $ — $ (125) Capital expenditures $ 7 $ 93 $ 8 $ — $ 108 Investments in unconsolidated affiliates, net $ 5 $ — $ — $ — $ 5 Year Ended December 31, 2020: Logistics and Marketing Gathering and Processing Other Eliminations Total (millions) Total operating revenue $ 5,530 $ 3,479 $ — $ (2,707) $ 6,302 Adjusted gross margin (a) $ 333 $ 1,226 $ — $ — $ 1,559 Operating and maintenance expense (36) (554) (17) — (607) General and administrative expense (7) (22) (224) — (253) Depreciation and amortization expense (13) (333) (30) — (376) Asset impairments — (746) — — (746) Other expense, net (10) (3) (2) — (15) Restructuring costs — — (9) — (9) Earnings (loss) from unconsolidated affiliates 510 (63) — — 447 Interest expense — — (302) — (302) Net income (loss) $ 777 $ (495) $ (584) $ — $ (302) Net (loss) attributable to noncontrolling interests — (4) — — (4) Net income (loss) attributable to partners $ 777 $ (499) $ (584) $ — $ (306) Non-cash derivative mark-to-market $ 78 $ (23) $ — $ — $ 55 Non-cash lower of cost or net realizable value adjustments $ 6 $ — $ — $ — $ 6 Capital expenditures $ 4 $ 140 $ 16 $ — $ 160 Investments in unconsolidated affiliates, net $ 101 $ — $ — $ — $ 101 Year Ended December 31, 2019: Logistics and Marketing Gathering and Processing Other Eliminations Total (millions) Total operating revenue $ 6,856 $ 4,319 $ — $ (3,550) $ 7,625 Adjusted gross margin (a) $ 254 $ 1,349 $ — $ — $ 1,603 Operating and maintenance expense (42) (664) (22) — (728) General and administrative expense (8) (23) (244) — (275) Depreciation and amortization expense (19) (355) (30) — (404) Asset impairments (35) (212) — — (247) Other expense, net (3) (5) — — (8) Loss on sale of assets, net (10) (70) — — (80) Restructuring costs — — (11) — (11) Earnings from unconsolidated affiliates 468 6 — — 474 Interest expense — — (304) — (304) Income tax expense — — 1 — 1 Net income (loss) $ 605 $ 26 $ (610) $ — $ 21 Net income attributable to noncontrolling interests — (4) — — (4) Net income (loss) attributable to partners $ 605 $ 22 $ (610) $ — $ 17 Non-cash derivative mark-to-market $ (29) $ (49) $ — $ — $ (78) Non-cash lower of cost or net realizable value adjustments $ 10 $ — $ — $ — $ 10 Capital expenditures $ 29 $ 474 $ 16 $ — $ 519 Investments in unconsolidated affiliates, net $ 450 $ — $ — $ — $ 450 December 31, December 31, 2021 2020 (millions) Segment long-term assets: Gathering and Processing $ 7,515 $ 7,788 Logistics and Marketing 3,887 3,929 Other (b) 229 232 Total long-term assets 11,631 11,949 Current assets 1,749 1,008 Total assets $ 13,380 $ 12,957 (a) Adjusted gross margin consists of total operating revenues, including commodity derivative activity, less purchases and related costs. Adjusted gross margin is viewed as a non-GAAP financial measure under the rules of the SEC, but is included as a supplemental disclosure because it is a primary performance measure used by management as it represents the results of product sales versus product purchases. As an indicator of our operating performance, adjusted gross margin should not be considered an alternative to, or more meaningful than, net income, net cash provided by operating activities or gross margin as determined in accordance with GAAP. Our adjusted gross margin may not be comparable to a similarly titled measure of another company because other entities may not calculate adjusted gross margin in the same manner.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information (Notes)	12 Months Ended
	Dec. 31, 2021
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Year Ended December 31, 2021 2020 2019 (millions) Cash paid for interest: Cash paid for interest, net of amounts capitalized $ 297 $ 283 $ 258 Cash paid for income taxes, net of income tax refunds $ 3 $ 3 $ 3 Non-cash investing and financing activities: Property, plant and equipment acquired with accounts payable and accrued liabilities $ 10 $ 7 $ 45 Other non-cash changes in property, plant and equipment $ (9) $ (3) $ (2) Other non-cash activities: Operating lease assets arising from the implementation of Topic 842 $ — $ — $ 84 Right-of-use assets obtained in exchange for operating and finance lease liabilities $ 48 $ 18 $ 82

Subsequent Events (Notes)

Subsequent Events (Notes)	Jan. 21, 2021
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events On January 24, 2022, we announced that the board of directors of the General Partner declared a quarterly distribution on our common units of $0.39 per common unit. The distribution was paid on February 14, 2022 to unitholders of record on February 4, 2022. On the same date, the board of directors of the General Partner declared a quarterly distribution on our Series B and Series C Preferred Units of $0.4922 and $0.4969 per unit, respectively. The Series B distributions will be paid on March 15, 2022 to unitholders of record on March 1, 2022. The Series C distribution will be paid on April 15, 2022 to unitholders of record on April 1, 2022. On January 3, 2022, we repaid, at par, prior to maturity all $350 million of aggregate principal amount outstanding of our 4.950% Senior Notes due April 1, 2022 using borrowings under our Revolving Credit Facility and AR Securitization Facility.

Description of Business and B_2

Description of Business and Basis of Presentation (Policies)	12 Months Ended
	Dec. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Business Description and Basis of Presentation [Text Block]	The consolidated financial statements have been prepared in accordance with GAAP. All intercompany balances and transactions have been eliminated in consolidation.

Accounting Policies (Policies)

Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Equity Method Investments	Investments in Unconsolidated Affiliates - We use the equity method to account for investments in greater than 20% owned affiliates.
Use of Estimates, Policy	Use of Estimates -
Receivables, Trade and Other Accounts Receivable, Allowance for Doubtful Accounts, Policy	Allowance for Credit Losses - Management estimates the amount of required allowances for credit losses based upon our assessment of various factors, including historical loss rates, the age of the accounts receivable balances, the credit quality of our customers, current economic conditions, reasonable and supportable forecasts of future economic conditions, and other relevant factors that may affect our ability to collect from customers.
Inventory, Policy	Inventories - Inventories, which consist primarily of NGLs and natural gas, are recorded at the lower of weighted-average cost or net realizable value. Transportation costs are included in inventory.
Derivatives, Methods of Accounting, Derivatives Not Designated or Qualifying as Hedges	Accounting for Risk Management Activities and Financial Instruments - Non-trading energy commodity derivatives are designated as a hedge of a forecasted transaction or future cash flow (cash flow hedge), a hedge of a recognized asset, liability or firm commitment (fair value hedge), or normal purchases or normal sales. The remaining non-trading derivatives, which are related to asset-based activities for which the normal purchase or normal sale exception is not elected, are recorded at fair value in the consolidated balance sheets as unrealized gains or unrealized losses in derivative instruments, with changes in the fair value recognized in the consolidated statements of operations. For each derivative, the accounting method and presentation of gains and losses or revenue and expense in the consolidated statements of operations are as follows: Classification of Contract Accounting Method Presentation of Gains & Losses or Revenue & Expense Trading Derivatives Mark-to-market method (a) Net basis in trading and marketing gains and losses Non-Trading Derivatives: Cash Flow Hedge Hedge method (b) Gross basis in the same consolidated statements of operations category as the related hedged item Fair Value Hedge Hedge method (b) Gross basis in the same consolidated statements of operations category as the related hedged item Normal Purchases or Normal Sales Accrual method (c) Gross basis upon settlement in the corresponding consolidated statements of operations category based on purchase or sale Other Non-Trading Derivative Activity Mark-to-market method (a) Net basis in trading and marketing gains and losses, net (a) Mark-to-market method - An accounting method whereby the change in the fair value of the asset or liability is recognized in the consolidated statements of operations in trading and marketing gains and losses, net during the current period. (b) Hedge method - An accounting method whereby the change in the fair value of the asset or liability is recorded in the consolidated balance sheets as unrealized gains or unrealized losses on derivative instruments. For cash flow hedges, there is no recognition in the consolidated statements of operations for the effective portion until the service is provided or the associated delivery impacts earnings. For fair value hedges, the change in the fair value of the asset or liability, as well as the offsetting changes in value of the hedged item, are recognized in the consolidated statements of operations in the same category as the related hedged item.
Derivatives, Policy	Cash Flow and Fair Value Hedges - For derivatives designated as a cash flow hedge or a fair value hedge, we maintain formal documentation of the hedge. In addition, we formally assess both at the inception of the hedging relationship and on an ongoing basis, whether the hedge contract is highly effective in offsetting changes in cash flows or fair values of hedged items. All components of each derivative gain or loss are included in the assessment of hedge effectiveness, unless otherwise noted. The fair value of a derivative designated as a cash flow hedge is recorded in the consolidated balance sheets as unrealized gains or unrealized losses on derivative instruments. The change in fair value of the effective portion of a derivative designated as a cash flow hedge is recorded in partners’ equity in accumulated other comprehensive income, or AOCI, and the ineffective portion is recorded in the consolidated statements of operations. During the period in which the hedged transaction impacts earnings, amounts in AOCI associated with the hedged transaction are reclassified to the consolidated statements of operations in the same line item as the item being hedged. Hedge accounting is discontinued prospectively when it is determined that the derivative no longer qualifies as an effective hedge, or when it is probable that the hedged transaction will not occur. When hedge accounting is discontinued because the derivative no longer qualifies as an effective hedge, the derivative is subject to the mark-to-market accounting method prospectively. The derivative continues to be carried on the consolidated balance sheets at its fair value; however, subsequent changes in its fair value are recognized in current period earnings. Gains and losses related to discontinued hedges that were previously accumulated in AOCI will remain in AOCI until the hedged transaction impacts earnings, unless it is probable that the hedged transaction will not occur, in which case, the gains and losses that were previously deferred in AOCI will be immediately recognized in current period earnings. The fair value of a derivative designated as a fair value hedge is recorded for balance sheet purposes as unrealized gains or unrealized losses on derivative instruments. We recognize the gain or loss on the derivative instrument, as well as the offsetting loss or gain on the hedged item in earnings in the current period. All derivatives designated and accounted for as fair value hedges are classified in the same category as the item being hedged in the results of operations. Valuation - When available, quoted market prices or prices obtained through external sources are used to determine a contract’s fair value. For contracts with a delivery location or duration for which quoted market prices are not available, fair value is determined based on pricing models developed primarily from historical relationships with quoted market prices and the expected relationship with quoted market prices.
Property, Plant and Equipment, Policy	Property, Plant and Equipment - Property, plant and equipment are recorded at historical cost. The cost of maintenance and repairs, which are not significant improvements, are expensed when incurred. Depreciation is computed using the straight-line method over the estimated useful lives of the assets.
Interest Capitalization, Policy	Capitalized Interest - We capitalize interest during construction of major projects. Interest is calculated on the monthly outstanding capital balance and ceases in the month that the asset is placed into service. We also capitalize interest on our equity method investments which are devoting substantially all efforts to establishing a new business and have not yet begun planned principal operations. Capitalization ceases when the investee commences planned principal operations. The rates used to calculate capitalized interest are the weighted-average cost of debt, including the impact of interest rate swaps.
Asset Retirement Obligation	Asset Retirement Obligations - Our asset retirement obligations relate primarily to the retirement of various gathering pipelines and processing facilities and obligations related to right-of-way and land easement agreements. We adjust our asset retirement obligation each quarter for any liabilities incurred or settled during the period, accretion expense and any revisions made to the estimated cash flows.
Goodwill and Intangible Assets, Intangible Assets, Policy	Intangible Assets - Intangible assets consist of customer contracts, including commodity purchase, transportation and processing contracts, and related relationships. These intangible assets are amortized on a straight-line basis over the period of expected future benefit. Intangible assets are removed from the gross carrying amount and the total of accumulated amortization in the period in which they become fully amortized.
Impairment or Disposal of Long-Lived Assets, Policy	Long-Lived Assets - We periodically evaluate whether the carrying value of long-lived assets, including intangible assets, has been impaired when circumstances indicate the carrying value of those assets may not be recoverable. This evaluation is based on undiscounted cash flow projections. The carrying amount is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. We consider various factors when determining if these assets should be evaluated for impairment, including but not limited to: • significant adverse change in legal factors or business climate; • a current-period operating or cash flow loss combined with a history of operating or cash flow losses, or a projection or forecast that demonstrates continuing losses associated with the use of a long-lived asset; • an accumulation of costs significantly in excess of the amount originally expected for the acquisition or construction of a long-lived asset; • significant adverse changes in the extent or manner in which an asset is used, or in its physical condition; • significant adverse change in the market value of an asset; or • a current expectation that, more likely than not, an asset will be sold or otherwise disposed of before the end of its estimated useful life.
Lessee, Leases	Leases - Our leasing activity primarily consists of transportation agreements, office space, vehicles, and field equipment. We determine if an arrangement is an operating or finance lease at inception. Right of use assets represent our right to use an underlying asset for the lease term when we control the use of the asset by obtaining substantially all of the economic benefits of the asset and direct the use of the asset. Lease liabilities represent our obligation to make lease payments arising from the lease. Right of use assets and lease liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. The interest rate used to calculate the present value of lease payments is the rate implicit in the lease when determinable or our incremental borrowing rate. Our incremental borrowing rate is primarily based on our collateralized borrowing rate when such borrowings exist or an estimated collateralized borrowing rate based on independent third party quotes when such borrowings do not exist. Our lease terms may include options to extend or terminate the lease when it is reasonably certain that we will exercise that option. Operating lease expense is recognized on a straight-line basis over the lease term. Finance lease expense is recognized based on the effective-interest method and amortization of the right of use asset is recognized based on the straight-line method. Practical expedients
Debt, Policy	Unamortized Debt Discount and Expense - Discounts and expenses incurred with the issuance of long-term debt are amortized over the term of the debt using the effective interest method. The discounts and unamortized expenses are recorded on the consolidated balance sheets within the carrying amount of long-term debt.
Interest in Unincorporated Joint Ventures or Partnerships, Policy	Noncontrolling Interest - Noncontrolling interest represents any third party or affiliate interest in non-wholly owned entities that we consolidate. For financial reporting purposes, the assets and liabilities of these entities are consolidated with those of our own, with any third party or affiliate interest in our consolidated balance sheet amounts shown as noncontrolling interest in equity. Distributions to and contributions from noncontrolling interests represent cash payments to and cash contributions from, respectively, such third party and affiliate investors.
Revenue Recognition, Policy	Revenue Recognition - Our operating revenues are primarily derived from the following activities: • sales of natural gas, NGLs and condensate; • services related to gathering, compressing, treating, and processing natural gas; and • services related to transportation and storage of natural gas and NGLs. Sales of natural gas, NGLs and condensate - We sell our commodities to a variety of customers ranging from large, multi-national petrochemical and refining companies to regional retail propane distributors. We recognize revenue from commodity sales at the point in time when control is obtained by the customer. Generally, the transaction price is determined at the time of each delivery as the variability of commodity pricing is resolved. Customers usually pay monthly based on the products purchased the previous month. Sales of natural gas, NGLs and condensate include physical sales contracts which qualify as financial derivative instruments, and buy-sell and exchange transactions which involve purchases and sales of inventory with the same counterparty that are legally contingent or in contemplation of one another as a single transaction on a combined net basis. Neither of these types of arrangements are contracts with customers within the scope of Financial Accounting Standards Board, or "FASB", Accounting Standards Update, or "ASU", 2014-09 Revenue from Contracts with Customers, or "Topic 606". Gathering, compressing, treating and processing natural gas - For natural gas gathering and processing activities, we receive either fees and/or a percentage of proceeds from commodity sales as payment for these services, depending on the type of contract. For gathering and processing agreements within the scope of Topic 606, we recognize the revenue associated with our services when the gas is gathered, treated or processed at our facilities. Under fee-based contracts, we receive a fee for our services based on throughput volumes. Under percent-of-proceeds contracts, we receive either an agreed upon percentage of the actual proceeds received from our sale of the residue natural gas and NGLs or an agreed upon percentage based on index related prices for the natural gas and NGLs. Our percent-of-proceeds contracts may also include a fee-based component. Transportation and storage - Revenue from transportation and storage agreements is recognized based on contracted volumes transported and stored in the period the services are provided. Our service contracts sometimes have terms that extend beyond one year, and are recognized over time. The performance obligation for most of our service contracts encompasses a series of distinct services performed on discrete daily quantities of natural gas or NGLs for purposes of allocating variable consideration and recognizing revenue while the customer simultaneously receives and consumes the benefits of the services provided. Revenue is recognized over time consistent with the transfer of goods or services over time to the customer based on daily volumes delivered or stored. Consideration is generally variable, and the transaction price cannot be determined at the inception of the contract, because the volume of natural gas or NGLs for which the service is provided is only specified on a daily or monthly basis. The transaction price is determined at the time the service is provided and the uncertainty is resolved. Customers usually pay monthly based on the services performed the previous month. Purchase arrangements - Under purchase arrangements, we purchase natural gas at either the wellhead or the tailgate of a plant. These purchase arrangements represent an arrangement with a supplier and are recorded in “Purchases and related costs”. Often, we earn fees for services performed prior to taking control of the product in these arrangements and service revenue is recorded for these fees. Revenue generated from the sale of product obtained in these purchase arrangements are reported as “Sales of natural gas, NGLs and condensate” on the consolidated statements of operations and are recognized on a gross basis as we purchase and take control of the product prior to sale and are the principal in the transaction. Practical expedients
Contract Liabilities, Policy	Contract liabilities - We have contracts with customers whereby the customer reimburses us for costs to construct certain connections to our operating assets. These agreements are typically entered into in contemplation with gathering and processing agreements and transportation agreements with customers, and are part of the consideration of the contract. We record these payments as deferred revenue which are amortized into revenue over the expected contract term.
Purchases and Related Costs	Purchases and related costs - Purchases and related costs primarily includes (i) the cost of purchased commodities, including NGLs, natural gas and condensate, and (ii) fees incurred for transportation and fractionation of commodities.
Major Customers, Policy	Significant Customers - There were no third party customers that accounted for more than 10% of total operating revenues for the years ended December 31, 2021, 2020 and 2019. We had significant transactions with affiliates for the years ended December 31, 2021, 2020 and 2019.
Environmental Costs, Policy	Environmental Expenditures - Environmental expenditures are expensed or capitalized as appropriate, depending upon the future economic benefit. Expenditures that relate to an existing condition caused by past operations and that do not generate current or future revenue are expensed. Liabilities for these expenditures are recorded on an undiscounted basis when environmental assessments and/or clean-ups are probable and the costs can be reasonably estimated.
Share-based Compensation, Option and Incentive Plans Policy	Equity-Based Compensation - Equity classified awards are measured at their grant date fair value, which is recognized on a straight line basis over the requisite service or vesting period. Equity classified awards are expected to result in the issuance of common units upon vesting. Liability classified equity-based compensation cost is remeasured at each reporting date at fair value, based on the closing security price, and is recognized as expense over the requisite service period. Compensation expense for awards with graded vesting provisions is recognized on a straight-line basis over the requisite service period of each separately vesting portion of the award.
Income Tax, Policy	Income Taxes - We are structured as a master limited partnership which is a pass-through entity for federal income tax purposes. Our income tax expense includes certain jurisdictions, including state, local, franchise and margin taxes of the master limited partnership and subsidiaries. We follow the asset and liability method of accounting for income taxes. Under this method, deferred income taxes are recognized for the tax consequences of temporary differences between the financial statement carrying amounts and the tax basis of the assets and liabilities. Our taxable income or loss, which may vary substantially from the net income or loss reported in the consolidated statements of operations, is proportionately included in the federal income tax returns of each partner.
Earnings Per Share, Policy	Net Income or Loss per Limited Partner Unit - Basic and diluted net income or loss per limited partner unit, or LPU, is calculated by dividing net income or loss allocable to limited partners, by the weighted-average number of outstanding LPUs during the period using the two-class method. Diluted net income or loss per limited partner unit is computed based on the weighted average number of limited partner units, plus the effect of dilutive potential units, if any, outstanding during the period.
Cash and Cash Equivalents, Restricted Cash and Cash Equivalents, Policy	Cash, Cash Equivalents, and Restricted Cash - We consider investments in highly liquid financial instruments purchased with an original stated maturity of 90 days or less and temporary investments of cash in short-term money market securities to be cash equivalents. Restricted cash primarily consists of amounts held in our non-qualified deferred compensation plan. Restricted cash is excluded from cash and cash equivalents and is included in other current or long-term assets.

Revenue Recognition (Tables)

Revenue Recognition (Tables)	12 Months Ended
	Dec. 31, 2021
Disaggregation of Revenue [Line Items]
Disaggregation of Revenue [Table Text Block]	Revenue RecognitionWe disaggregate our revenue from contracts with customers by type of contract for each of our reportable segments, as we believe it best depicts the nature, timing and uncertainty of our revenue and cash flows. The following tables set forth our revenue by those categories: Year Ended December 31, 2021 Logistics and Marketing Gathering and Processing Eliminations Total (millions) Sales of natural gas $ 3,798 $ 2,824 $ (2,614) $ 4,008 Sales of NGLs and condensate (a) 6,133 3,952 (3,307) 6,778 Transportation, processing and other 65 474 — 539 Trading and marketing losses, net (b) (262) (356) — (618) Total operating revenues $ 9,734 $ 6,894 $ (5,921) $ 10,707 (a) Includes $2,111 million for the year ended December 31, 2021 of revenues from physical sales contracts and buy-sell exchange transactions in our Logistics and Marketing segment, which is net of $2,590 million of buy-sell purchases related to buy-sell revenues of $2,857 million which are not within the scope of FASB ASC 606 "Revenue from Contractors with Customer" ("Topic 606"). (b) Not within the scope of Topic 606. Year Ended December 31, 2020 Logistics and Marketing Gathering and Processing Eliminations Total (millions) Sales of natural gas $ 1,786 $ 1,384 $ (1,263) $ 1,907 Sales of NGLs and condensate (a) 3,569 1,658 (1,443) 3,784 Transportation, processing and other 51 405 (1) 455 Trading and marketing gains, net (b) 124 32 — 156 Total operating revenues $ 5,530 $ 3,479 $ (2,707) $ 6,302 (a) Includes $1,786 million of revenues for the year ended December 31, 2020, from physical sales contracts and buy-sell exchange transactions in our Logistics and Marketing segment, which is net of $1,004 million of buy-sell purchases related to buy-sell revenues of $1,300 million which are not within the scope of Topic 606. (b) Not within the scope of Topic 606. Year Ended December 31, 2019 Logistics and Marketing Gathering and Processing Eliminations Total (millions) Sales of natural gas $ 2,098 $ 1,734 $ (1,525) $ 2,307 Sales of NGLs and condensate (a) 4,744 2,171 (2,023) 4,892 Transportation, processing and other 46 395 (2) 439 Trading and marketing (losses) gains, net (b) (32) 19 — (13) Total operating revenues $ 6,856 $ 4,319 $ (3,550) $ 7,625 (a) Includes $3,236 million for the year ended December 31, 2019 of revenues from physical sales contracts and buy-sell exchange transactions in our Logistics and Marketing segment, which are not within the scope of Topic 606. (b) Not within the scope of Topic 606. The revenue expected to be recognized in the future related to performance obligations that are not satisfied is approximately $442 million as of December 31, 2021. Our remaining performance obligations primarily consist of minimum volume commitment fee arrangements and are expected to be recognized through 2031 with a weighted average remaining life of three years as of December 31, 2021. As a practical expedient permitted by Topic 606, this amount excludes variable consideration as well as remaining performance obligations that have original expected durations of one year or less, as applicable. Our remaining performance obligations also exclude estimates of variable rate escalation clauses in our contracts with customers.
Revenue from External Customers by Products and Services [Table Text Block]	Revenue RecognitionWe disaggregate our revenue from contracts with customers by type of contract for each of our reportable segments, as we believe it best depicts the nature, timing and uncertainty of our revenue and cash flows. The following tables set forth our revenue by those categories: Year Ended December 31, 2021 Logistics and Marketing Gathering and Processing Eliminations Total (millions) Sales of natural gas $ 3,798 $ 2,824 $ (2,614) $ 4,008 Sales of NGLs and condensate (a) 6,133 3,952 (3,307) 6,778 Transportation, processing and other 65 474 — 539 Trading and marketing losses, net (b) (262) (356) — (618) Total operating revenues $ 9,734 $ 6,894 $ (5,921) $ 10,707 (a) Includes $2,111 million for the year ended December 31, 2021 of revenues from physical sales contracts and buy-sell exchange transactions in our Logistics and Marketing segment, which is net of $2,590 million of buy-sell purchases related to buy-sell revenues of $2,857 million which are not within the scope of FASB ASC 606 "Revenue from Contractors with Customer" ("Topic 606"). (b) Not within the scope of Topic 606. Year Ended December 31, 2020 Logistics and Marketing Gathering and Processing Eliminations Total (millions) Sales of natural gas $ 1,786 $ 1,384 $ (1,263) $ 1,907 Sales of NGLs and condensate (a) 3,569 1,658 (1,443) 3,784 Transportation, processing and other 51 405 (1) 455 Trading and marketing gains, net (b) 124 32 — 156 Total operating revenues $ 5,530 $ 3,479 $ (2,707) $ 6,302 (a) Includes $1,786 million of revenues for the year ended December 31, 2020, from physical sales contracts and buy-sell exchange transactions in our Logistics and Marketing segment, which is net of $1,004 million of buy-sell purchases related to buy-sell revenues of $1,300 million which are not within the scope of Topic 606. (b) Not within the scope of Topic 606. Year Ended December 31, 2019 Logistics and Marketing Gathering and Processing Eliminations Total (millions) Sales of natural gas $ 2,098 $ 1,734 $ (1,525) $ 2,307 Sales of NGLs and condensate (a) 4,744 2,171 (2,023) 4,892 Transportation, processing and other 46 395 (2) 439 Trading and marketing (losses) gains, net (b) (32) 19 — (13) Total operating revenues $ 6,856 $ 4,319 $ (3,550) $ 7,625 (a) Includes $3,236 million for the year ended December 31, 2019 of revenues from physical sales contracts and buy-sell exchange transactions in our Logistics and Marketing segment, which are not within the scope of Topic 606. (b) Not within the scope of Topic 606. The revenue expected to be recognized in the future related to performance obligations that are not satisfied is approximately $442 million as of December 31, 2021. Our remaining performance obligations primarily consist of minimum volume commitment fee arrangements and are expected to be recognized through 2031 with a weighted average remaining life of three years as of December 31, 2021. As a practical expedient permitted by Topic 606, this amount excludes variable consideration as well as remaining performance obligations that have original expected durations of one year or less, as applicable. Our remaining performance obligations also exclude estimates of variable rate escalation clauses in our contracts with customers.

Contract Liabilities (Tables)

Contract Liabilities (Tables)	12 Months Ended
	Dec. 31, 2021
Contract Assets and Liabilities [Abstract]
Contract with Customer, Asset and Liability [Table Text Block]	December 31, 2021 2020 (millions) Balance, beginning of period $ 35 $ 33 Additions 1 3 Revenue recognized (a) (2) (1) Balance, end of period $ 34 $ 35

Agreements and Transactions w_2

Agreements and Transactions with Affiliates (Tables)	12 Months Ended
	Dec. 31, 2021
Related Party Transaction [Line Items]
Schedule of Fees Incurred and Other Fees Paid	The following table summarizes employee related costs that were charged by DCP Midstream, LLC to the Partnership that are included in the consolidated statements of operations: Year Ended December 31, 2021 2020 2019 (millions) Employee related costs charged by DCP Midstream, LLC Operating and maintenance expense $ 157 $ 160 $ 197 General and administrative expense $ 149 $ 165 $ 189 Restructuring costs $ — $ 9 $ 11
Summary of Transactions with Affiliates	The following table summarizes our transactions with affiliates: Year Ended December 31, 2021 2020 2019 (millions) Phillips 66 (including its affiliates): Sales of natural gas, NGLs and condensate to affiliates $ 3,000 $ 1,037 $ 1,140 Purchases and related costs from affiliates $ 62 $ 96 $ 142 Transportation and related costs from affiliates $ 158 $ 113 $ 67 Operating and maintenance and general administrative expenses $ 14 $ 11 $ 13 Enbridge (including its affiliates): Sales of natural gas, NGLs and condensate to affiliates $ 2 $ 2 $ (2) Purchases and related costs from affiliates $ 40 $ 20 $ 26 Transportation and related costs from affiliates $ 1 $ 1 $ 1 Operating and maintenance and general administrative expenses $ 1 $ 2 $ 2 Unconsolidated affiliates: Sales of natural gas, NGLs and condensate to affiliates $ 103 $ 49 $ 38 Transportation, processing, and other to affiliates $ 18 $ 13 $ 4 Purchases and related costs from affiliates $ 86 $ 50 $ 70 Transportation and related costs from affiliates $ 825 $ 836 $ 783 We had balances with affiliates as follows: December 31, 2021 December 31, 2020 (millions) Phillips 66 (including its affiliates): Accounts receivable $ 361 $ 217 Accounts payable $ 114 $ 89 Other assets $ 1 $ 1 Enbridge (including its affiliates): Accounts payable $ 4 $ 2 Unconsolidated affiliates: Accounts receivable $ 28 $ 21 Accounts payable $ 87 $ 70

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Dec. 31, 2021
Inventory Disclosure [Abstract]
Schedule of Inventories	Inventories were as follows: December 31, 2021 December 31, 2020 (millions) Natural gas $ 43 $ 18 NGLs 34 20 Total inventories $ 77 $ 38

Property, Plant and Equipment_2

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2021
Property, Plant and Equipment [Abstract]
Classification of Property, Plant and Equipment	A summary of property, plant and equipment by classification is as follows: Depreciable December 31, 2021 December 31, 2020 (millions) Gathering and transmission systems 20 — 50 Years $ 7,645 $ 7,680 Processing, storage and terminal facilities 35 — 60 Years 5,057 4,986 Other 3 — 30 Years 585 585 Finance lease assets 2 — 5 Years 28 25 Construction work in progress 103 144 Property, plant and equipment 13,418 13,420 Accumulated depreciation (5,717) (5,427) Property, plant and equipment, net $ 7,701 $ 7,993
Schedule of Asset Retirement Obligations	The following table summarizes changes in the asset retirement obligations included in our balance sheets: December 31, 2021 (a) 2020 (a) (millions) Balance, beginning of period $ 150 $ 141 Accretion expense 10 $ 9 Dispositions (2) $ — Balance, end of period $ 158 $ 150 (a) Asset retirement obligations are included in other long-term liabilities in the consolidated balance sheets. Accretion expense is recorded within operating and maintenance expense in our consolidated statement of operations. Accretion expense for the year ended December 31, 2019 was $9 million.

Goodwill and Intangible Asset_2

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2021
Goodwill Disclosure [Abstract]
Schedule of Goodwill [Table Text Block]	The carrying amount of goodwill in each of our reportable segments was as follows: Gathering and Processing Logistics and Marketing Total (millions) Balance, December 31, 2019 $ 159 $ — $ 159 Impairment (159) — (159) Balance, December 31, 2020 $ — $ — $ —
Schedule of Finite-Lived Intangible Assets	Intangible assets consist of customer contracts, including commodity purchase, transportation and processing contracts and related relationships. The gross carrying amount and accumulated amortization of these intangible assets are included in the accompanying consolidated balance sheets as intangible assets, net, and are as follows: December 31, December 31, 2021 2020 (millions) Gross carrying amount $ 110 $ 111 Accumulated amortization (71) (67) Intangible assets, net $ 39 $ 44
Schedule of Finite-Lived Intangible Assets, Future Amortization Expense	Estimated future amortization for these intangible assets is as follows: Estimated Future Amortization (millions) 2022 $ 4 2023 4 2024 4 2025 4 2026 4 Thereafter 19 Total $ 39

Investments in Unconsolidated_2

Investments in Unconsolidated Affiliates (Tables)	12 Months Ended
	Dec. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Investments in Unconsolidated Affiliates	The following table summarizes our investments in unconsolidated affiliates: Carrying Value as of Percentage December 31, December 31, 2020 (millions) DCP Sand Hills Pipeline, LLC 66.67% $ 1,703 $ 1,723 DCP Southern Hills Pipeline, LLC 66.67% 728 734 Gulf Coast Express LLC 25.00% 422 436 Front Range Pipeline LLC 33.33% 195 198 Texas Express Pipeline LLC 10.00% 94 97 Mont Belvieu 1 Fractionator 20.00% 6 7 Discovery Producer Services LLC 40.00% 231 244 Cheyenne Connector, LLC 50.00% 148 152 Mont Belvieu Enterprise Fractionator 12.50% 28 26 Panola Pipeline Company, LLC 15.00% 20 21 Other Various 3 3 Total investments in unconsolidated affiliates $ 3,578 $ 3,641
Schedule Of Earnings From Investment In Unconsolidated Affiliates [Table Text Block]	: Year Ended December 31, 2021 2020 2019 (millions) DCP Sand Hills Pipeline, LLC $ 274 $ 279 $ 287 DCP Southern Hills Pipeline, LLC 91 78 77 Gulf Coast Express LLC 63 66 27 Front Range Pipeline LLC 38 38 32 Texas Express Pipeline LLC 19 18 16 Mont Belvieu 1 Fractionator 17 12 13 Discovery Producer Services LLC (a) 16 (63) 6 Cheyenne Connector, LLC 12 6 — Mont Belvieu Enterprise Fractionator 3 11 14 Other 2 2 2 Total earnings from unconsolidated affiliates $ 535 $ 447 $ 474
Equity Method Investment Summarized Financial Information, Statement of Operations [Table Text Block]	The following tables summarize the combined financial information of our investments in unconsolidated affiliates: Year Ended December 31, 2021 2020 2019 (millions) Statements of operations: Operating revenue $ 2,110 $ 2,049 $ 1,798 Operating expenses $ 844 $ 746 $ 695 Net income $ 1,261 $ 1,297 $ 1,103
Equity Method Investment Summarized Financial Information Balance Sheet Table [Table Text Block]	December 31, December 31, (millions) Balance sheets: Current assets $ 429 $ 355 Long-term assets 7,277 7,510 Current liabilities (200) (177) Long-term liabilities (254) (258) Net assets $ 7,252 $ 7,430

Fair Value Measurement (Tables)

Fair Value Measurement (Tables)	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Details of Impairment of Long-Lived Assets Held and Used by Asset	The following table presents certain assets and asset groups measured at fair value on a non-recurring basis, by consolidated balance sheet caption as of the date of measurement. Asset Impairments Fair Value 2021 2020 (millions) Long-lived assets $ 1 $ 31 Long-lived assets (a) 96 $ 587 Goodwill — 159 Direct investment in unconsolidated affiliate 256 61 Total $ 31 $ 807
Financial Instruments Carried at Fair Value	December 31, 2021 December 31, 2020 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) Current assets: Commodity derivatives $ 24 $ 62 $ — $ 86 $ 21 $ 42 $ — $ 63 Short-term investments (a) $ 4 $ 1 $ — $ 5 $ — $ — $ — $ — Long-term assets: Commodity derivatives $ — $ 8 $ 2 $ 10 $ 1 $ 13 $ 2 $ 16 Investments in marketable securities (a) $ 28 $ — $ — $ 28 22 $ 1 $ — $ 23 Current liabilities: Commodity derivatives $ (42) $ (100) $ (3) $ (145) $ (19) $ (34) $ (3) $ (56) Long-term liabilities: Commodity derivatives $ (1) $ (25) $ (4) $ (30) $ — $ (6) $ (1) $ (7)
Fair Value Assets and Liabilities Measured On Recurring Basis Unobservable Input Reconciliation	Commodity Derivative Instruments Current Long-Term Current Long-Term (millions) Year ended December 31, 2021 (a): Beginning balance $ — $ 2 $ (3) $ (1) Net unrealized losses included in earnings — — (10) (6) Transfers out of Level 3 — — 3 3 Settlements — — 7 — Ending balance $ — $ 2 $ (3) $ (4) Net unrealized gains (losses) on derivatives still held included in earnings $ — $ 1 $ (3) $ (4) Year ended December 31, 2020 (a): Beginning balance $ 4 $ — $ (1) $ (3) Net unrealized (losses) gains included in earnings (1) 5 5 2 Transfers out of Level 3 — (3) — — Settlements (3) — (7) — Ending balance $ — $ 2 $ (3) $ (1) Net unrealized gains (losses) on derivatives still held included in earnings $ — $ 2 $ (3) $ (1) (a) There were no purchases, issuances or sales of derivatives or transfers into Level 3 for the years ended December 31, 2021 and 2020.
Schedule of Valuation Processes	December 31, 2021 Product Group Fair Value Valuation Techniques Unobservable Input Forward Weighted Average (a) (millions) Assets Natural gas $ 2 Market approach Longer dated forward curve prices $2.22-$3.37 $2.86 Per MMBtu Liabilities NGLs $ (4) Market approach Longer dated forward curve prices $0.30-$1.82 $0.93 Per gallon Natural gas $ (3) Market approach Longer dated forward curve prices $2.17-$3.55 $2.57 Per MMBtu
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments [Table Text Block]	December 31, 2021 and December 31, 2020, the carrying value and fair value of our total debt, including current maturities, were as follows: December 31, 2021 December 31, 2020 Carrying Value (a) Fair Value Carrying Value (a) Fair Value (millions) Total debt $ 5,445 $ 6,107 $ 5,635 $ 5,938

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Schedule of Leasing Assets and Liabilities [Table Text Block]	Location in Consolidated Balance Sheet As of December 31, 2021 December 31, 2020 (millions) Assets Operating lease assets Operating lease assets $ 104 $ 85 Finance lease assets Property, plant and equipment 28 25 Total right of use assets $ 132 $ 110 Liabilities Current liabilities Operating lease liabilities Other current liabilities $ 26 $ 24 Finance lease liabilities Current debt 5 5 Noncurrent liabilities Operating lease liabilities Operating lease liabilities $ 93 $ 76 Finance lease liabilities Long-term debt 21 22 Total lease liabilities $ 145 $ 127
Lease, Cost [Table Text Block]	Location in Consolidated Statement of Operations Year Ended December 31, 2021 2020 (millions) Operating lease cost Operating and maintenance expense $ 28 $ 27 Finance lease cost Amortization of right of use assets Depreciation and amortization expense 3 2 Interest on lease liabilities Interest expense 1 1 Variable lease cost Operating and maintenance expense 6 6 Short term lease cost Operating and maintenance expense 4 4 Total lease cost $ 42 $ 40
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	Future Minimum Lease Payments as of December 31, 2021 Operating Leases Finance Leases (millions) 2022 $ 29 $ 6 2023 28 6 2024 19 7 2025 15 3 2026 9 5 Thereafter 33 5 Total lease payments $ 133 $ 32 Less imputed interest (14) (6) Total lease liabilities $ 119 $ 26
Leases - Other Information	Year Ended December 31, 2021 2020 (millions) Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 30 $ 27 Operating cash flows from finance leases 5 4 Financing cash flows from finance leases 1 1 Right-of-use assets obtained in exchange for operating lease obligations: $ 44 $ 13 Right-of-use assets obtained in exchange for finance lease obligations: $ 4 $ 5 Other information related to operating leases as follows: Weighted average remaining lease term 6 years 6 years Weighted average discount rate 4.00 % 4.00 % Other information related to finance leases as follows: Weighted average remaining lease term 4 years 5 years Weighted average discount rate 3.00 % 3.00 %

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Schedule of Debt	December 31, 2021 December 31, 2020 (millions) Senior notes: Issued September 2011, interest at 4.750% payable semi-annually, due September 2021 $ — $ 500 Issued March 2012, interest at 4.950% payable semi-annually, due April 2022 350 350 Issued March 2013, interest at 3.875% payable semi-annually, due March 2023 500 500 Issued July 2018 and January 2019, interest at 5.375% payable semi-annually, due July 2025 825 825 Issued June 2020, interest at 5.625% payable semi-annually, due July 2027 500 500 Issued May 2019, interest at 5.125% payable semi-annually, due May 2029 600 600 Issued August 2000, interest at 8.125% payable semi-annually, due August 2030 (a) 300 300 Issued November 2021, interest at 3.250% payable semi-annually, due February 2032 400 — Issued October 2006, interest at 6.450% payable semi-annually, due November 2036 300 300 Issued September 2007, interest at 6.750% payable semi-annually, due September 2037 450 450 Issued March 2014, interest at 5.600% payable semi-annually, due April 2044 400 400 Junior subordinated notes: Issued May 2013, interest at 5.850% payable semi-annually, due May 2043 550 550 Accounts receivable securitization facility: Accounts receivable securitization facility, interest at 1.000% as of December 31, 2021, due August 2024 260 350 Fair value adjustments related to interest rate swap fair value hedges (a) 16 17 Unamortized issuance costs (38) (38) Unamortized discount, net (6) (7) Finance lease liabilities 26 27 Total debt 5,433 5,624 Current finance lease liabilities 5 5 Current debt 350 500 Total long-term debt $ 5,078 $ 5,119
Future Maturities of Long-Term Debt	The maturities of our debt as of December 31, 2021 are as follows: Debt (millions) 2022 $ 350 2023 500 2024 260 2025 825 2026 — Thereafter 3,500 Total debt $ 5,435

Risk Management and Hedging A_2

Risk Management and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Summary of Gross and Net Amounts of Derivative Instruments	December 31, 2021 December 31, 2020 Gross Amounts Amounts Not Net Gross Amounts Amounts Not Net (millions) Assets: Commodity derivatives $ 96 $ — $ 96 $ 79 $ — $ 79 Liabilities: Commodity derivatives $ (175) $ — $ (175) $ (63) $ — $ (63)
Schedule of Designated and Non-Designated Derivative Instruments in Statement of Financial Position, Fair Value	The fair value of our derivative instruments that are marked-to-market each period, as well as the location of each within our consolidated balance sheets, by major category, is summarized below. We have no derivative instruments that are designated as hedging instruments for accounting purposes as of December 31, 2021 and December 31, 2020. Balance Sheet Line Item December 31, December 31, Balance Sheet Line Item December 31, December 31, (millions) (millions) Derivative Assets Not Designated as Hedging Instruments: Derivative Liabilities Not Designated as Hedging Instruments: Commodity derivatives: Commodity derivatives: Unrealized gains on derivative instruments — current $ 86 $ 63 Unrealized losses on derivative instruments — current $ (145) $ (56) Unrealized gains on derivative instruments — long-term 10 16 Unrealized losses on derivative instruments — long-term (30) (7) Total $ 96 $ 79 Total $ (175) $ (63)
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) [Table Text Block]	The following summarizes the balance and activity within AOCI relative to our interest rate, commodity and foreign currency cash flow hedges as of and for the year ended December 31, 2021: Interest Commodity Foreign Total (millions) Net deferred (losses) gains in AOCI (beginning balance) $ (2) $ (6) $ 1 $ (7) Losses reclassified from AOCI to earnings — effective portion 1 — — 1 Net deferred (losses) gains in AOCI (ending balance) $ (1) $ (6) $ 1 $ (6) Deferred losses in AOCI expected to be reclassified into earnings over the next 12 months $ — $ — $ — $ — (a) Relates to Discovery, an unconsolidated affiliate. The following summarizes the balance and activity within AOCI relative to our interest rate, commodity and foreign currency cash flow hedges as of and for the year ended December 31, 2020: Interest Commodity Foreign Total (millions) Net deferred (losses) gains in AOCI (beginning balance) $ (2) $ (6) $ 1 $ (7) Net deferred (losses) gains in AOCI (ending balance) $ (2) $ (6) $ 1 $ (7) Deferred losses in AOCI expected to be reclassified into earnings over the next 12 months $ — $ — $ — $ — (a) Relates to Discovery, an unconsolidated affiliate.
Schedule of Changes in Derivative Instruments Not Designated as Hedging Instruments	Commodity Derivatives: Statements of Operations Line Item Year Ended December 31, 2021 2020 2019 (millions) Realized (losses) gains $ (493) $ 101 $ 65 Unrealized (losses) gains (125) 55 (78) Trading and marketing (losses) gains, net $ (618) $ 156 $ (13)
Schedule of Net Long or Short Positions Expected to be Realized	December 31, 2021 Crude Oil Natural Gas Natural Gas Natural Gas Year of Expiration Net Short Net (Short) Long Position Net Short Net (Short) Long 2022 (1,133,000) (76,565,200) (5,080,635) (7,015,000) 2023 (446,000) 912,500 (1,344,000) (830,000) 2024 — — (1,455,000) (2,280,000) 2025 — — (1,440,000) 9,530,000 2026 — — (1,440,000) 535,000 December 31, 2020 Crude Oil Natural Gas Natural Gas Natural Gas Year of Expiration Net Short Net Short Position Net Short Net Long (Short) 2021 (1,969,000) (69,887,800) (9,857,339) (7,130,000) 2022 (214,000) (36,500,000) (1,422,842) 10,950,000 2023 — — (1,440,000) 3,650,000 2024 — — (1,440,000) 2,140,000 2025 — — (1,320,000) 1,825,000

Partnership Equity and Distri_2

Partnership Equity and Distributions (Tables)	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Cash Distribution	Payment Date Per Unit Total Cash (millions) Distributions to common unitholders November 12, 2021 $ 0.39 $ 81 August 13, 2021 $ 0.39 $ 81 May 14, 2021 $ 0.39 $ 82 February 12, 2021 $ 0.39 $ 81 November 13, 2020 $ 0.39 $ 81 August 14, 2020 $ 0.39 $ 82 May 15, 2020 $ 0.39 $ 81 February 14, 2020 $ 0.78 $ 162 November 14, 2019 $ 0.78 $ 155 August 14, 2019 $ 0.78 $ 154 May 15, 2019 $ 0.78 $ 155 February 14, 2019 $ 0.78 $ 154 Distributions to Series A Preferred unitholders December 15, 2021 $ 36.8750 $ 19 June 15, 2021 $ 36.8750 $ 18 December 15, 2020 $ 36.8750 $ 19 June 15, 2020 $ 36.8750 $ 18 December 16, 2019 $ 36.8750 $ 19 June 17, 2019 $ 36.8750 $ 18 Distributions to Series B Preferred unitholders December 15, 2021 $ 0.4922 $ 3 September 15, 2021 $ 0.4922 $ 4 June 15, 2021 $ 0.4922 $ 3 March 15, 2021 $ 0.4922 $ 3 December 15, 2020 $ 0.4922 $ 4 September 15, 2020 $ 0.4922 $ 3 June 15, 2020 $ 0.4922 $ 3 March 16, 2020 $ 0.4922 $ 3 December 16, 2019 $ 0.4922 $ 4 September 16, 2019 $ 0.4922 $ 3 June 17, 2019 $ 0.4922 $ 3 March 15, 2019 $ 0.4922 $ 3 Distributions to Series C Preferred unitholders October 15, 2021 $ 0.4969 $ 3 July 15, 2021 $ 0.4969 $ 2 April 15, 2021 $ 0.4969 $ 2 January 15, 2021 $ 0.4969 $ 2 October 15, 2020 $ 0.4969 $ 2 July 15, 2020 $ 0.4969 $ 3 April 15, 2020 $ 0.4969 $ 2 January 15, 2020 $ 0.4969 $ 2 October 15, 2019 $ 0.4969 $ 2 July 15, 2019 $ 0.4969 $ 3 April 15, 2019 $ 0.4969 $ 2 January 15, 2019 $ 0.5576 $ 2

Equity-Based Compensation (Tabl

Equity-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2021
Share-based Payment Arrangement [Abstract]
Schedule of Fair Value of Unvested Awards	Vesting Period (years) Unrecognized Estimated Weighted-Average Remaining Vesting DCP Midstream LTIP: SPUs 3 $ 7 0% - 11% 2 Phantom Units 1 - 3 $ 7 0% - 11% 1
Schedule of Nonvested Share Activity	Units Grant Date Weighted-Average Price Per Unit Measurement Date Weighted-Average Price Per Unit Outstanding at January 1, 2019 251,319 $ 43.33 Granted 222,440 $ 30.60 Forfeited (40,348) $ 34.95 Vested (a) (83,054) $ 56.80 Outstanding at December 31, 2019 350,357 $ 33.02 Granted 296,700 $ 23.71 Forfeited (76,183) $ 27.45 Vested (b) (141,613) $ 36.23 Outstanding at December 31, 2020 429,261 $ 26.52 Granted 323,460 $ 19.44 Forfeited (54,641) $ 21.32 Vested (c) (173,171) $ 30.60 Outstanding at December 31, 2021 524,909 $ 21.35 $ 27.48 Expected to vest 481,926 $ 21.35 27.48 (a) The 2017 grants vested at 120%. (b) The 2018 grants vested at 152%. (c) The 2019 grants vested at 150% Units Grant Date Weighted-Average Price Per Unit Measurement Date Weighted-Average Price Per Unit Outstanding at January 1, 2019 231,706 $ 42.55 Granted 281,930 $ 30.52 Forfeited (43,170) $ 34.14 Vested (171,881) $ 40.92 Outstanding at December 31, 2019 298,585 $ 33.35 Granted 671,040 $ 20.07 Forfeited (78,320) $ 22.99 Vested (123,817) $ 36.25 Outstanding at December 31, 2020 767,488 $ 22.33 Granted 403,130 $ 21.64 Forfeited (221,480) $ 20.43 Vested (362,116) $ 24.88 Outstanding at December 31, 2021 587,022 $ 20.99 $ 22.80 Expected to vest 523,046 $ 20.98 $ 22.80
Share-based Compensation Arrangements by Share-based Payment Award, Performance-Based Units, Vested and Expected to Vest [Table Text Block]	Units Fair Value of Units Vested Unit-Based Liabilities Paid (millions) Vested or paid in cash in 2019 83,054 $ 6 $ 9 Vested or paid in cash in 2020 141,613 $ 4 $ 6 Vested or paid in cash in 2021 173,171 $ 7 $ 4 Units Fair Value of Units Vested Unit-Based Liabilities Paid (millions) Vested or paid in cash in 2019 171,881 $ 6 $ 5 Vested or paid in cash in 2020 123,817 $ 3 $ 6 Vested or paid in cash in 2021 362,116 $ 5 $ 3

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	Year Ended December 31, 2021 2020 2019 (millions, except per unit amounts) Net income (loss) attributable to limited partners $ 332 $ (365) $ (160) Weighted average limited partner units outstanding, basic 208,366,254 208,338,544 153,116,233 Dilutive effects of nonvested restricted phantom units 233,804 — — Weighted average limited partner units outstanding, diluted 208,600,058 208,338,544 153,116,233 Net income (loss) per limited partner unit, basic and diluted $ 1.59 $ (1.75) $ (1.05)

Business Segments (Tables)

Business Segments (Tables)	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Segment Information	Year Ended December 31, 2021 Logistics and Marketing Gathering and Processing Other Eliminations Total (millions) Total operating revenue $ 9,734 $ 6,894 $ — $ (5,921) $ 10,707 Adjusted gross margin (a) $ 138 $ 1,304 $ — $ — $ 1,442 Operating and maintenance expense (38) (603) (18) — (659) General and administrative expense (6) (15) (202) — (223) Depreciation and amortization expense (12) (325) (27) — (364) Asset impairments (13) (18) — — (31) Other income (expense), net 6 (1) — — 5 Gain (loss) on sale of assets, net 2 (7) — — (5) Earnings from unconsolidated affiliates 519 16 — — 535 Interest expense — — (299) — (299) Income tax expense — — (6) — (6) Net income (loss) $ 596 $ 351 $ (552) $ — $ 395 Net income attributable to noncontrolling interests — (4) — — (4) Net income (loss) attributable to partners $ 596 $ 347 $ (552) $ — $ 391 Non-cash derivative mark-to-market $ (19) $ (106) $ — $ — $ (125) Capital expenditures $ 7 $ 93 $ 8 $ — $ 108 Investments in unconsolidated affiliates, net $ 5 $ — $ — $ — $ 5 Year Ended December 31, 2020: Logistics and Marketing Gathering and Processing Other Eliminations Total (millions) Total operating revenue $ 5,530 $ 3,479 $ — $ (2,707) $ 6,302 Adjusted gross margin (a) $ 333 $ 1,226 $ — $ — $ 1,559 Operating and maintenance expense (36) (554) (17) — (607) General and administrative expense (7) (22) (224) — (253) Depreciation and amortization expense (13) (333) (30) — (376) Asset impairments — (746) — — (746) Other expense, net (10) (3) (2) — (15) Restructuring costs — — (9) — (9) Earnings (loss) from unconsolidated affiliates 510 (63) — — 447 Interest expense — — (302) — (302) Net income (loss) $ 777 $ (495) $ (584) $ — $ (302) Net (loss) attributable to noncontrolling interests — (4) — — (4) Net income (loss) attributable to partners $ 777 $ (499) $ (584) $ — $ (306) Non-cash derivative mark-to-market $ 78 $ (23) $ — $ — $ 55 Non-cash lower of cost or net realizable value adjustments $ 6 $ — $ — $ — $ 6 Capital expenditures $ 4 $ 140 $ 16 $ — $ 160 Investments in unconsolidated affiliates, net $ 101 $ — $ — $ — $ 101 Year Ended December 31, 2019: Logistics and Marketing Gathering and Processing Other Eliminations Total (millions) Total operating revenue $ 6,856 $ 4,319 $ — $ (3,550) $ 7,625 Adjusted gross margin (a) $ 254 $ 1,349 $ — $ — $ 1,603 Operating and maintenance expense (42) (664) (22) — (728) General and administrative expense (8) (23) (244) — (275) Depreciation and amortization expense (19) (355) (30) — (404) Asset impairments (35) (212) — — (247) Other expense, net (3) (5) — — (8) Loss on sale of assets, net (10) (70) — — (80) Restructuring costs — — (11) — (11) Earnings from unconsolidated affiliates 468 6 — — 474 Interest expense — — (304) — (304) Income tax expense — — 1 — 1 Net income (loss) $ 605 $ 26 $ (610) $ — $ 21 Net income attributable to noncontrolling interests — (4) — — (4) Net income (loss) attributable to partners $ 605 $ 22 $ (610) $ — $ 17 Non-cash derivative mark-to-market $ (29) $ (49) $ — $ — $ (78) Non-cash lower of cost or net realizable value adjustments $ 10 $ — $ — $ — $ 10 Capital expenditures $ 29 $ 474 $ 16 $ — $ 519 Investments in unconsolidated affiliates, net $ 450 $ — $ — $ — $ 450 December 31, December 31, 2021 2020 (millions) Segment long-term assets: Gathering and Processing $ 7,515 $ 7,788 Logistics and Marketing 3,887 3,929 Other (b) 229 232 Total long-term assets 11,631 11,949 Current assets 1,749 1,008 Total assets $ 13,380 $ 12,957 (a) Adjusted gross margin consists of total operating revenues, including commodity derivative activity, less purchases and related costs. Adjusted gross margin is viewed as a non-GAAP financial measure under the rules of the SEC, but is included as a supplemental disclosure because it is a primary performance measure used by management as it represents the results of product sales versus product purchases. As an indicator of our operating performance, adjusted gross margin should not be considered an alternative to, or more meaningful than, net income, net cash provided by operating activities or gross margin as determined in accordance with GAAP. Our adjusted gross margin may not be comparable to a similarly titled measure of another company because other entities may not calculate adjusted gross margin in the same manner.

Statement of Cash Flows, Supple

Statement of Cash Flows, Supplemental Disclosures (Tables)	12 Months Ended
	Dec. 31, 2021
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract]
Summary of Supplemental Cash Flow Information	Year Ended December 31, 2021 2020 2019 (millions) Cash paid for interest: Cash paid for interest, net of amounts capitalized $ 297 $ 283 $ 258 Cash paid for income taxes, net of income tax refunds $ 3 $ 3 $ 3 Non-cash investing and financing activities: Property, plant and equipment acquired with accounts payable and accrued liabilities $ 10 $ 7 $ 45 Other non-cash changes in property, plant and equipment $ (9) $ (3) $ (2) Other non-cash activities: Operating lease assets arising from the implementation of Topic 842 $ — $ — $ 84 Right-of-use assets obtained in exchange for operating and finance lease liabilities $ 48 $ 18 $ 82

Description of Business and B_3

Description of Business and Basis of Presentation - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2021
Investments in Greater Than 20%
Business Acquisition [Line Items]
Equity method ownership investment (as percent)	20.00%
Investments in Less Than 20%
Business Acquisition [Line Items]
Equity method ownership investment (as percent)	20.00%
DCP Midstream, LLC | DCP Midstream GP, LLC
Business Acquisition [Line Items]
Ownership interest percentage by parent	100.00%
DCP Midstream, LLC | DCP Midstream LP
Business Acquisition [Line Items]
Ownership interest percentage by parent	57.00%
Phillips 66 | DCP Midstream, LLC
Business Acquisition [Line Items]
Ownership interest percentage by parent	50.00%
Enbridge | DCP Midstream, LLC
Business Acquisition [Line Items]
Ownership interest percentage by parent	50.00%

Dispositions (Details)

Dispositions (Details) - USD ($) $ in Millions	Jan. 30, 2019	Dec. 31, 2021
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, [Line Items]
Proceeds from Sales of Business, Affiliate and Productive Assets	$ 103
Loss on Disposition of Business	9
Proceeds from Divestiture of Businesses	$ 90
Non-core Assets [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, [Line Items]
Proceeds from Sales of Business, Affiliate and Productive Assets		$ 106
Loss on Disposition of Business		$ 71

Revenue Recognition (Details)

Revenue Recognition (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Trading and marketing gains (losses), net	$ (618)	$ 156	$ (13)
Total operating revenues	10,707	6,302	7,625
Revenue, Remaining Performance Obligation, Amount	$ 442
Revenue, Performance Obligation, Description of Timing	three years
Revenue from contract with customer not within the scope of Topic 606	$ 2,111	1,786	3,236
Buy-Sell Purchases	2,590	1,004
Buy-Sell Revenues	2,857	1,300
Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate	4,008	1,907	2,307
NGLs and Condensate [Member]
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate	6,778	3,784	4,892
Transportation, Processing and Other [Member]
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate	539	455	439
Gathering and Processing
Disaggregation of Revenue [Line Items]
Trading and marketing gains (losses), net	(356)	32	19
Total operating revenues	6,894	3,479	4,319
Gathering and Processing | Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate	2,824	1,384	1,734
Gathering and Processing | NGLs and Condensate [Member]
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate	3,952	1,658	2,171
Gathering and Processing | Transportation, Processing and Other [Member]
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate	474	405	395
Logistics and Marketing
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate	65	51
Trading and marketing gains (losses), net	(262)	124	(32)
Total operating revenues	9,734	5,530	6,856
Logistics and Marketing | Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate	3,798	1,786	2,098
Logistics and Marketing | NGLs and Condensate [Member]
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate	6,133	3,569	4,744
Logistics and Marketing | Transportation, Processing and Other [Member]
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate	65	51	46
Eliminations
Disaggregation of Revenue [Line Items]
Trading and marketing gains (losses), net	0	0	0
Total operating revenues	(5,921)	(2,707)	(3,550)
Eliminations | Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate	(2,614)	(1,263)	(1,525)
Eliminations | NGLs and Condensate [Member]
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate	$ (3,307)	(1,443)	(2,023)
Eliminations | Transportation, Processing and Other [Member]
Disaggregation of Revenue [Line Items]
Sales of natural gas, NGLs and condensate		$ (1)	$ (2)

Contract Liabilities (Details)

Contract Liabilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Contract Assets and Liabilities [Abstract]
Contract with Customer, Liability	$ 34	$ 35	$ 33
Contract with Customer, Liability, Additions	1	3
Contract with Customer, Liability, Revenue Recognized	$ (2)	$ (1)
Contract with Customer, Timing of Satisfaction of Performance Obligation and Payment	35 years

Agreements and Transactions w_3

Agreements and Transactions with Affiliates - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Recovery of Direct Costs	$ 5
Operating Expense
Related Party Transaction [Line Items]
Employee related costs	157	$ 160	$ 197
General and Administrative Expense
Related Party Transaction [Line Items]
Employee related costs	149	165	189
Restructuring costs
Related Party Transaction [Line Items]
Employee related costs	$ 0	$ 9	$ 11

Agreements and Transactions w_4

Agreements and Transactions with Affiliates - Transactions with Affiliates (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Operating and maintenance expense	$ 659	$ 607	$ 728
Affiliated Entity | Phillips 66
Related Party Transaction [Line Items]
Operating and maintenance expense	14	11	13
Natural Gas, NGLs and Condensate [Member] | Affiliated Entity | Unconsolidated Affiliates
Related Party Transaction [Line Items]
Sales of natural gas, NGLs and condensate	103	49	38
Purchases and related costs	86	50	70
Natural Gas, NGLs and Condensate [Member] | Affiliated Entity | Phillips 66
Related Party Transaction [Line Items]
Sales of natural gas, NGLs and condensate	3,000	1,037	1,140
Purchases and related costs	62	96	142
Natural Gas, NGLs and Condensate [Member] | Affiliated Entity | Enbridge
Related Party Transaction [Line Items]
Sales of natural gas, NGLs and condensate	2	2	(2)
Purchases and related costs	40	20	26
Operating and maintenance expense	1	2	2
Transportation, Processing and Other [Member]
Related Party Transaction [Line Items]
Sales of natural gas, NGLs and condensate	539	455	439
Transportation, Processing and Other [Member] | Affiliated Entity | Unconsolidated Affiliates
Related Party Transaction [Line Items]
Sales of natural gas, NGLs and condensate	18	13	4
Purchases and related costs	825	836	783
Transportation, Processing and Other [Member] | Affiliated Entity | Phillips 66
Related Party Transaction [Line Items]
Purchases and related costs	158	113	67
Transportation, Processing and Other [Member] | Affiliated Entity | Enbridge
Related Party Transaction [Line Items]
Purchases and related costs	$ 1	$ 1	$ 1

Agreements and Transactions w_5

Agreements and Transactions with Affiliates - Balances with Affiliates (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
Accounts receivable	$ 389	$ 238
Accounts payable	205	161
Unconsolidated Affiliates
Related Party Transaction [Line Items]
Accounts receivable	28	21
Accounts payable	87	70
Phillips 66
Related Party Transaction [Line Items]
Accounts receivable	361	217
Accounts payable	114	89
Related Party Transaction, Due from (to) Related Party, Noncurrent	1	1
Enbridge
Related Party Transaction [Line Items]
Accounts payable	$ 4	$ 2

Inventories - Schedule of Inven

Inventories - Schedule of Inventories (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Components Of Inventory [Line Items]
Total inventories	$ 77	$ 38
Natural Gas [Member]
Components Of Inventory [Line Items]
Total inventories	43	18
Natural Gas Liquids
Components Of Inventory [Line Items]
Total inventories	$ 34	$ 20

Inventories - Additional Inform

Inventories - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Inventory Disclosure [Abstract]
Lower of cost or net realizable value adjustment	$ 0	$ 6	$ 10

Property, Plant and Equipment -

Property, Plant and Equipment - Classification of Property, Plant and Equipment (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 13,418	$ 13,420
Accumulated depreciation	(5,717)	(5,427)
Property, plant and equipment, net	7,701	7,993
Interest capitalized on construction projects	2	7	$ 13
Gathering and transmission systems
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 7,645	7,680
Gathering and transmission systems | Minimum
Property, Plant and Equipment [Line Items]
Depreciable life of property, plant and equipment	20 years
Gathering and transmission systems | Maximum
Property, Plant and Equipment [Line Items]
Depreciable life of property, plant and equipment	50 years
Processing, storage and terminal facilities
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 5,057	4,986
Processing, storage and terminal facilities | Minimum
Property, Plant and Equipment [Line Items]
Depreciable life of property, plant and equipment	35 years
Processing, storage and terminal facilities | Maximum
Property, Plant and Equipment [Line Items]
Depreciable life of property, plant and equipment	60 years
Other
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 585	585
Other | Minimum
Property, Plant and Equipment [Line Items]
Depreciable life of property, plant and equipment	3 years
Other | Maximum
Property, Plant and Equipment [Line Items]
Depreciable life of property, plant and equipment	30 years
Finance lease assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 28	25
Finance lease assets [Member] | Minimum
Property, Plant and Equipment [Line Items]
Depreciable life of property, plant and equipment	2 years
Finance lease assets [Member] | Maximum
Property, Plant and Equipment [Line Items]
Depreciable life of property, plant and equipment	5 years
Construction work in progress
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 103	$ 144

Property, Plant and Equipment_3

Property, Plant and Equipment - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Interest capitalized on construction projects	$ 2	$ 7	$ 13
Depreciation expense	$ 358	$ 370	$ 396

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Asset Retirement Obligation	$ 158	$ 150	$ 141
Accretion Expense	10	9	$ 9
Asset Retirement Obligation, Period Increase (Decrease)	$ (2)	$ 0

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Goodwill [Line Items]
Goodwill	$ 0	$ 159
Goodwill, Impairment Loss, Net of Tax	159
Gathering and Processing
Goodwill [Line Items]
Goodwill	0	159
Goodwill, Impairment Loss, Net of Tax	159
Logistics and Marketing
Goodwill [Line Items]
Goodwill	0	$ 0
Goodwill, Impairment Loss, Net of Tax	$ 0

Intangible Assets (Details)

Intangible Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Goodwill Disclosure [Abstract]
Finite-Lived Intangible Assets, Amortization Expense, Year One	$ 4
Finite-Lived Intangible Assets, Amortization Expense, Year Two	4
Finite-Lived Intangible Assets, Amortization Expense, Year Three	4
Finite-Lived Intangible Assets, Amortization Expense, Year Four	4
Finite-Lived Intangible Assets, Amortization Expense, Year Five	4
Finite-Lived Intangible Assets, Amortization Expense, after Year Five	19
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	110	$ 111
Finite-Lived Intangible Assets, Accumulated Amortization	71	67
Intangible assets, net	39	44
Amortization of Intangible Assets	$ 6	$ 6	$ 8
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	10 years
Minimum
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Asset, Useful Life	1 year
Maximum
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Asset, Useful Life	13 years

Investments In Unconsolidated_3

Investments In Unconsolidated Affiliates - Investments In Unconsolidated Affiliates (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 3,578	$ 3,641
Earnings from unconsolidated affiliates	$ 535	447	$ 474
DCP Sand Hills Pipeline, LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership investment (as percent)	66.67%
Investments in unconsolidated affiliates	$ 1,703	1,723
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	590	605
Earnings from unconsolidated affiliates	$ 274	279	287
DCP Southern Hills Pipeline, LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership investment (as percent)	66.67%
Investments in unconsolidated affiliates	$ 728	734
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	132	135
Earnings from unconsolidated affiliates	$ 91	78	77
Front Range Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership investment (as percent)	33.33%
Investments in unconsolidated affiliates	$ 195	198
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	4	4
Earnings from unconsolidated affiliates	$ 38	38	32
Gulf Coast Express [Member]
Schedule of Equity Method Investments [Line Items]
Equity method ownership investment (as percent)	25.00%
Investments in unconsolidated affiliates	$ 422	436
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	1	1
Earnings from unconsolidated affiliates	$ 63	66	27
Texas Express Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership investment (as percent)	10.00%
Investments in unconsolidated affiliates	$ 94	97
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	2	2
Earnings from unconsolidated affiliates	$ 19	18	16
Cheyenne Connector
Schedule of Equity Method Investments [Line Items]
Equity method ownership investment (as percent)	50.00%
Investments in unconsolidated affiliates	$ 148	152
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	4	4
Earnings from unconsolidated affiliates	$ 12	6	0
Mont Belvieu Enterprise Fractionator
Schedule of Equity Method Investments [Line Items]
Equity method ownership investment (as percent)	12.50%
Investments in unconsolidated affiliates	$ 28	26
Earnings from unconsolidated affiliates	$ 3	11	14
Mont Belvieu 1 Fractionator
Schedule of Equity Method Investments [Line Items]
Equity method ownership investment (as percent)	20.00%
Investments in unconsolidated affiliates	$ 6	7
Earnings from unconsolidated affiliates	$ 17	12	13
Discovery Producer Services LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership investment (as percent)	40.00%
Investments in unconsolidated affiliates	$ 231	244
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	1	(8)
Earnings from unconsolidated affiliates	$ 16	(63)	6
Panola Pipeline Company, LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership investment (as percent)	15.00%
Investments in unconsolidated affiliates	$ 20	21
Other
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	3	3
Earnings from unconsolidated affiliates	$ 2	$ 2	$ 2

Investments in Unconsolidated_4

Investments in Unconsolidated Affiliates - Earnings from Investments in Unconsolidated Affiliates (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Schedule of Equity Method Investments [Line Items]
Earnings from unconsolidated affiliates	$ 535	$ 447	$ 474
DCP Sand Hills Pipeline, LLC
Schedule of Equity Method Investments [Line Items]
Earnings from unconsolidated affiliates	274	279	287
DCP Southern Hills Pipeline, LLC
Schedule of Equity Method Investments [Line Items]
Earnings from unconsolidated affiliates	91	78	77
Front Range Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Earnings from unconsolidated affiliates	38	38	32
Gulf Coast Express [Member]
Schedule of Equity Method Investments [Line Items]
Earnings from unconsolidated affiliates	63	66	27
Texas Express Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Earnings from unconsolidated affiliates	19	18	16
Cheyenne Connector
Schedule of Equity Method Investments [Line Items]
Earnings from unconsolidated affiliates	12	6	0
Mont Belvieu Enterprise Fractionator
Schedule of Equity Method Investments [Line Items]
Earnings from unconsolidated affiliates	3	11	14
Mont Belvieu 1 Fractionator
Schedule of Equity Method Investments [Line Items]
Earnings from unconsolidated affiliates	17	12	13
Discovery Producer Services LLC
Schedule of Equity Method Investments [Line Items]
Earnings from unconsolidated affiliates	16	(63)	6
Other
Schedule of Equity Method Investments [Line Items]
Earnings from unconsolidated affiliates	$ 2	$ 2	$ 2

Investments in Unconsolidated_5

Investments in Unconsolidated Affiliates - Equity Method Investment Summarized Financial Information, Statement of Operations (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Schedule of Equity Method Statement of Operations [Line Items]
Total operating revenues	$ 10,707	$ 6,302	$ 7,625
Net (loss) income	395	(302)	21
Unconsolidated Affiliates
Schedule of Equity Method Statement of Operations [Line Items]
Total operating revenues	2,110	2,049	1,798
Operating Expenses	844	746	695
Net (loss) income	$ 1,261	$ 1,297	$ 1,103

Investments in Unconsolidated_6

Investments in Unconsolidated Affiliates - Equity Method Investment Summarized Financial Information, Balance Sheet (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Schedule of Equity Method Balance Sheet [Line Items]
Current assets	$ 1,749	$ 1,008
Long-term assets	11,631	11,949
Total current liabilities	2,010	1,621
Total assets	13,380	12,957
Total operating revenues	10,707	6,302	$ 7,625
Net (loss) income	395	(302)	21
Unconsolidated Affiliates
Schedule of Equity Method Balance Sheet [Line Items]
Current assets	429	355
Long-term assets	7,277	7,510
Total current liabilities	200	177
Liabilities, Noncurrent	254	258
Total assets	7,252	7,430
Total operating revenues	2,110	2,049	1,798
Operating Expenses	844	746	695
Net (loss) income	$ 1,261	$ 1,297	$ 1,103

Fair Value Measurement - Impair

Fair Value Measurement - Impairment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Impaired Long-Lived Assets Held and Used [Line Items]
Asset Impairment	$ 31	$ 746	$ 247
Property, Plant, and Equipment	1	96
Goodwill		0
Equity Method Investments, Fair Value Disclosure		256
Property, plant, and equipment impairment	31	587
Goodwill, Impairment Loss		159
Total Impairment Charges, including Equity Method Investments	$ 31	807
Equity Method Investment, Other than Temporary Impairment		61
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Impairment of Intangible Assets (Excluding Goodwill)		$ (11)

Fair Value Measurement - Financ

Fair Value Measurement - Financial Instruments Carried at Fair Value (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current Assets
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$ 0	$ 0	$ 4
Net realized and unrealized gains (losses) included in earnings	0	(1)
Transfers out of Level 3	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	0	(3)
Net unrealized gains (losses) on derivatives still held included in earnings	0	0
Current Assets | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - assets	86	63
Current Assets | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Restricted Investments, at Fair Value	5	0
Long- Term Assets
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	2	2	0
Net realized and unrealized gains (losses) included in earnings	0	5
Transfers out of Level 3	0	(3)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	0	0
Net unrealized gains (losses) on derivatives still held included in earnings	1	2
Long- Term Assets | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - assets	10	16
Long- Term Assets | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Restricted Investments, at Fair Value	28	23
Current Liabilities
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value	3	(3)	1
Net realized and unrealized (losses) gains included in earnings	(10)	5
Transfers out of Level 3	(3)	0
Settlements	7	(7)
Net unrealized gains (losses) on derivatives still held included in earnings	(3)	(3)
Current Liabilities | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - liabilities	145	56
Long- Term Liabilities
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value	4	(1)	$ 3
Net realized and unrealized (losses) gains included in earnings	(6)	2
Transfers out of Level 3	(3)
Settlements	0	0
Net unrealized gains (losses) on derivatives still held included in earnings	(4)	(1)
Long- Term Liabilities | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - liabilities	30	7
Level 1 | Current Assets | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - assets	24	21
Level 1 | Current Assets | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Restricted Investments, at Fair Value	4	0
Level 1 | Long- Term Assets | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - assets	0	1
Level 1 | Long- Term Assets | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Restricted Investments, at Fair Value	28	22
Level 1 | Current Liabilities | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - liabilities	42	19
Level 1 | Long- Term Liabilities | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - liabilities	1	0
Level 2 | Current Assets | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - assets	62	42
Level 2 | Current Assets | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Restricted Investments, at Fair Value	1	0
Level 2 | Long- Term Assets | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - assets	8	13
Level 2 | Long- Term Assets | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Restricted Investments, at Fair Value	0	1
Level 2 | Current Liabilities | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - liabilities	100	34
Level 2 | Long- Term Liabilities | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - liabilities	25	6
Level 3 | Current Assets | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - assets	0	0
Level 3 | Current Assets | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Restricted Investments, at Fair Value	0	0
Level 3 | Long- Term Assets | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - assets	2	2
Level 3 | Long- Term Assets | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Restricted Investments, at Fair Value	0	0
Level 3 | Current Liabilities | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - liabilities	3	3
Level 3 | Long- Term Liabilities | Commodity derivatives
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Commodity derivatives - liabilities	$ 4	$ (1)

Fair Value Measurement - Conden

Fair Value Measurement - Condensed Consolidated Balance Sheets for Derivative Financial Instruments (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Current Assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	$ 0	$ 4
Net realized and unrealized gains (losses) included in earnings	0	(1)
Transfers out of Level 3	0	0
Settlements	0	(3)
Ending balance	0	0
Net unrealized gains (losses) on derivatives still held included in earnings	0	0
Long- Term Assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	2	0
Net realized and unrealized gains (losses) included in earnings	0	5
Transfers out of Level 3	0	(3)
Settlements	0	0
Ending balance	2	2
Net unrealized gains (losses) on derivatives still held included in earnings	1	2
Current Liabilities
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Transfers out of Level 3	(3)	0
Net unrealized gains (losses) on derivatives still held included in earnings	(3)	(3)
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	3	(1)
Net realized and unrealized (losses) gains included in earnings	(10)	5
Settlements	7	(7)
Ending balance	(3)	3
Long- Term Liabilities
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Transfers out of Level 3	(3)
Net unrealized gains (losses) on derivatives still held included in earnings	(4)	(1)
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	1	(3)
Net realized and unrealized (losses) gains included in earnings	(6)	2
Transfers out of Level 3		0
Settlements	0	0
Ending balance	$ (4)	$ 1

Schedule of Valuation Processes

Schedule of Valuation Processes (Detail) - Level 3 - Market Approach Valuation Technique $ in Millions	Dec. 31, 2021USD ($)$ / gal
Derivative Liabilities | Natural Gas Liquids
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]
Liabilities, fair value | $	$ (4)
Derivative Liabilities | Natural Gas Liquids | Minimum
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]
Forward curve prices	0.30
Derivative Liabilities | Natural Gas Liquids | Maximum
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]
Forward curve prices	1.82
Derivative Liabilities | Natural Gas Liquids | Weighted Average [Member]
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]
Forward curve prices	0.93
Derivative Liabilities | Natural Gas [Member]
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]
Liabilities, fair value | $	$ (3)
Derivative Liabilities | Natural Gas [Member] | Minimum
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]
Forward curve prices	2.17
Derivative Liabilities | Natural Gas [Member] | Maximum
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]
Forward curve prices	3.55
Derivative Liabilities | Natural Gas [Member] | Weighted Average [Member]
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]
Forward curve prices	2.57
Derivative Assets | Natural Gas [Member]
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]
Assets | $	$ 2
Derivative Assets | Natural Gas [Member] | Minimum
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]
Forward curve prices	2.22
Derivative Assets | Natural Gas [Member] | Maximum
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]
Forward curve prices	3.37
Derivative Assets | Natural Gas [Member] | Weighted Average [Member]
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]
Forward curve prices	2.86

Carrying Value and Fair Value o

Carrying Value and Fair Value of Debt (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Fair Value Disclosures [Abstract]
Total Debt, Carrying Value	$ 5,445	$ 5,635
Total Debt, Fair Value	$ 6,107	$ 5,938

Leases, Additional Information

Leases, Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Lessee, Lease, Description [Line Items]
Operating Lease Extension Term	20 years
Operating Lease, Payments	$ 30	$ 27
Finance Lease, Interest Payment on Liability	5	4
Finance Lease, Principal Payments	1	1
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	$ 44	$ 13
Finance Lease, Weighted Average Remaining Lease Term	4 years	5 years
Finance Lease, Weighted Average Discount Rate, Percent	3.00%	3.00%
Right-of-Use Asset Obtained in Exchange for Finance Lease Liability	$ 4	$ 5
Operating Lease, Weighted Average Remaining Lease Term	6 years	6 years
Operating Lease, Weighted Average Discount Rate, Percent	4.00%	4.00%
Minimum
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Renewal Term	1 year
Lessee, Finance Lease, Renewal Term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Renewal Term	19 years
Lessee, Finance Lease, Renewal Term	19 years

Schedule of Leased Assets and L

Schedule of Leased Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating lease assets	$ 104	$ 85
Finance lease assets	28	25
Total right of use assets	132	110
Operating Lease, Liability, Current	26	24
Finance Lease, Liability, Current	5	5
Operating lease liabilities	93	76
Finance Lease, Liability, Noncurrent	21	22
Total lease liabilities	$ 145	$ 127

Leases, Lease Cost (Details)

Leases, Lease Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Income and Expenses, Lessee [Abstract]
Operating Lease, Cost	$ 28	$ 27
Finance Lease, Right-of-Use Asset, Amortization	3	2
Finance Lease, Interest Expense	1	1
Variable Lease, Cost	6	6
Short-term Lease, Cost	4	4
Lease, Cost	$ 42	$ 40

Leases, Schedule of Minimum Ope

Leases, Schedule of Minimum Operating and Finance Lease Payments (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Lessee, Operating Lease, Liability, Payments, Year One	$ 29
Lessee, Operating Lease, Liability, Payments, Due Year Two	28
Lessee, Operating Lease, Liability, Payments, Due Year Three	19
Lessee, Operating Lease, Liability, Payments, Due Year Four	15
Lessee, Operating Lease, Liability, Payments, Due Year Five	9
Lessee, Operating Lease, Liability, Payments, Due after Year Five	33
Lessee, Operating Lease, Liability, Payments, Due	133
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	14
Operating Lease, Liability	119
Finance Lease, Liability, Payments, Year One	6
Finance Lease, Liability, Payments, Due Year Two	6
Finance Lease, Liability, Payments, Due Year Three	7
Finance Lease, Liability, Payments, Due Year Four	3
Finance Lease, Liability, Payments, Due Year Five	5
Finance Lease, Liability, Payments, Due after Year Five	5
Finance Lease, Liability, Payments, Due	32
Finance Lease, Liability, Undiscounted Excess Amount	6
Finance Lease, Liability	$ 26	$ 27

Leases, Supplemental Cash Flow

Leases, Supplemental Cash Flow and Other Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Lessee Disclosure [Abstract]
Operating Lease, Payments	$ 30	$ 27
Finance Lease, Interest Payment on Liability	5	4
Finance Lease, Principal Payments	1	1
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	44	13
Right-of-Use Asset Obtained in Exchange for Finance Lease Liability	$ 4	$ 5
Operating Lease, Weighted Average Remaining Lease Term	6 years	6 years
Finance Lease, Weighted Average Remaining Lease Term	4 years	5 years
Operating Lease, Weighted Average Discount Rate, Percent	4.00%	4.00%
Finance Lease, Weighted Average Discount Rate, Percent	3.00%	3.00%

Debt - Schedule of Debt (Detail

Debt - Schedule of Debt (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Jun. 30, 2021	Dec. 31, 2020
Facility [Line Items]
Fair value adjustments related to interest rate swap fair value hedges	$ 16		$ 17
Unamortized issuance costs	(38)		(38)
Unamortized discount	(6)		(7)
Finance Lease, Liability	26		27
Total debt	5,433		5,624
Finance Lease, Liability, Current	5		5
Current debt	350		500
Long-term debt	5,078		5,119
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Proceeds from Debt, Net of Issuance Costs	396
Accounts Receivable Securitization Facility
Facility [Line Items]
Accounts Receivable Securitization Agreement	$ 260		350
Weighted-average variable interest rate	1.00%
Accounts Recievable included in the Securitization Transaction	$ 1,175
Senior Notes | Issued September 2011, interest at 4.750% payable semiannually, due September 2021
Facility [Line Items]
Senior Notes	$ 0	$ 500	500
Debt interest rate percentage	4.75%	4.75%
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Debt Instrument, Face Amount	$ 0	$ 500	500
Senior Notes | Issued March 2012, interest at 4.950% payable semi-annually, due April 2022
Facility [Line Items]
Senior Notes	$ 350		350
Debt interest rate percentage	4.95%
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Debt Instrument, Face Amount	$ 350		350
Senior Notes | Issued March 2013, interest at 3.875% payable semi-annually, due March 2023
Facility [Line Items]
Senior Notes	$ 500		500
Debt interest rate percentage	3.875%
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Debt Instrument, Face Amount	$ 500		500
Senior Notes | Issued July 2018 and January 2019, interest at 5.375% payable semi-annually, due July 2025
Facility [Line Items]
Senior Notes	$ 825		825
Debt interest rate percentage	5.375%
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Debt Instrument, Face Amount	$ 825		825
Senior Notes | Issued June 2020, interest at 5.625% payable semi-annually, due July 2027
Facility [Line Items]
Senior Notes	$ 500		500
Debt interest rate percentage	5.625%
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Debt Instrument, Face Amount	$ 500		500
Senior Notes | Issued May 2019, interest at 5.125% payable semiannually, due May 2029
Facility [Line Items]
Senior Notes	$ 600		600
Debt interest rate percentage	5.125%
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Debt Instrument, Face Amount	$ 600		600
Senior Notes | Issued August 2000, interest at 8.125% payable semi-annually, due August 2030
Facility [Line Items]
Senior Notes	$ 300		300
Debt interest rate percentage	8.125%
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Debt Instrument, Face Amount	$ 300		300
Senior Notes | Issued October 2006, interest at 6.450% payable semi-annually, due November 2036
Facility [Line Items]
Senior Notes	$ 300		300
Debt interest rate percentage	6.45%
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Debt Instrument, Face Amount	$ 300		300
Senior Notes | Issued September 2007, interest at 6.750% payable semi-annually, due September 2037
Facility [Line Items]
Senior Notes	$ 450		450
Debt interest rate percentage	6.75%
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Debt Instrument, Face Amount	$ 450		450
Senior Notes | Issued March 2014, interest at 5.600% payable semi-annually, due April 2044
Facility [Line Items]
Senior Notes	$ 400		400
Debt interest rate percentage	5.60%
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Debt Instrument, Face Amount	$ 400		400
Senior Notes | Senior Notes Three Point Two Five Percent Due February Twenty Thirty Two
Facility [Line Items]
Senior Notes	$ 400		0
Debt interest rate percentage	3.25%
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Debt Instrument, Face Amount	$ 400		0
Junior subordinated notes | Issued May 2013, interest at 5.850% payable semi-annually, due May 2043
Facility [Line Items]
Senior Notes	$ 550		550
Debt interest rate percentage	5.85%
Debt Instrument, Interest Rate, Stated Percentage [Abstract]
Debt Instrument, Face Amount	$ 550		$ 550

Debt - Additional Information (

Debt - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Jun. 30, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Line of Credit Facility, Borrowing Capacity, Description	$ 500
Accounts Receivable Securitization Facility
Debt Instrument [Line Items]
Accounts Recievable included in the Securitization Transaction	1,175
Credit Agreement
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,400
Basis spread determined by credit rating	0.35%
Commitment fee percentage	0.275%
Letter of credit amount outstanding	$ (17)
Debt covenants, maximum borrowing amount	$ 1,383
Credit Agreement | LIBOR
Debt Instrument [Line Items]
Variable rate basis spread	1.35%
Credit Agreement | Federal Funds Rate
Debt Instrument [Line Items]
Variable rate basis spread	0.50%
Credit Agreement | LIBOR Market Index
Debt Instrument [Line Items]
Variable rate basis spread	1.00%
Credit Agreement | Maximum
Debt Instrument [Line Items]
Maximum leverage ratio in event of acquisition	5.5
Credit Agreement | Quarters After June 30, 2018 | Maximum
Debt Instrument [Line Items]
Maximum leverage ratio	5
Credit Agreement | Quarters After June 30, 2018 | Minimum
Debt Instrument [Line Items]
Maximum leverage ratio	1
Issued July 2018 and January 2019, interest at 5.375% payable semi-annually, due July 2025 | Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.375%
Debt Instrument, Face Amount	$ 825		$ 825
Issued May 2019, interest at 5.125% payable semiannually, due May 2029 | Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.125%
Debt Instrument, Face Amount	$ 600		600
Issued September 2011, interest at 4.750% payable semiannually, due September 2021 | Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.75%	4.75%
Debt Instrument, Face Amount	$ 0	$ 500	$ 500

Debt - Future Maturities of Lon

Debt - Future Maturities of Long-Term Debt (Detail) $ in Millions	Dec. 31, 2021USD ($)
Maturities of Long-term Debt [Abstract]
2022	$ 350
2023	500
2024	260
2025	825
2026	0
Thereafter	3,500
Long Term Debt Maturities Repayments Of Principal Total	$ 5,435

Risk Management and Hedging A_3

Risk Management and Hedging Activities - Additional Information (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Derivative [Line Items]
Collateral, cash deposits	$ 128
Letters of credit received	131
Unrealized gains on derivative instruments	86	$ 63
Unrealized gains on derivative instruments	10	16
Derivative Instruments and Hedges, Liabilities	(145)	(56)
Derivative Instruments and Hedges, Liabilities, Noncurrent	$ (30)	$ (7)

Risk Management and Hedging A_4

Risk Management and Hedging Activities - Summary of Gross and Net Amounts of Derivative Instruments (Detail) - Commodity derivatives - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Offsetting Assets [Line Items]
Gross Amounts of Assets Presented in the Balance Sheet	$ 96	$ 79
Derivative Asset, Not Offset in Balance Sheet	0	0
Net Amount	96	79
Offsetting Liabilities [Line Items]
Gross Amounts of Liabilities Presented in the Balance Sheet	175	63
Derivative Liability, Not Offset in Balance Sheet	0	0
Net Amount	$ 175	$ 63

Risk Management and Hedging A_5

Risk Management and Hedging Activities - Schedule of Designated and Non-Designated Derivative Instruments in Statement of Financial Position, Fair Value (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Derivative Asset [Abstract]
Derivative Instruments and Hedges, Current Assets	$ 86	$ 63
Derivative Instruments and Hedges, Assets, Noncurrent	10	16
Derivative Liability [Abstract]
Derivative Instruments and Hedges, Current Liabilities	145	56
Derivative Instruments and Hedges, Liabilities, Noncurrent	30	7
Commodity derivatives | Derivative Asset Not Designated As Hedging Instruments [Member]
Derivative Asset [Abstract]
Derivative Instruments and Hedges, Current Assets	86	63
Derivative Instruments and Hedges, Assets, Noncurrent	10	16
Derivative Instruments Not Designated as Hedging Instruments, Total Assets, at Fair Value	96	79
Commodity derivatives | Derivative Liabilities Not Designated As Hedging Instruments [Member]
Derivative Liability [Abstract]
Derivative Instruments and Hedges, Current Liabilities	145	56
Derivative Instruments and Hedges, Liabilities, Noncurrent	30	7
Derivative Instruments Not Designated as Hedging Instruments, Total Liabilities, at Fair Value	$ 175	$ 63

Risk Management and Hedging A_6

Risk Management and Hedging Activities - Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative [Line Items]
Accumulated Other Comprehensive (Loss) Income	$ (6)	$ (7)
Trading and marketing gains (losses), net	(618)	156	$ (13)
Commodity derivatives | Derivative Assets Not Designated As Hedging Instruments
Derivative [Line Items]
Realized gains	(493)	101	65
Unrealized gains (losses)	(125)	55	(78)
Trading and marketing gains (losses), net	(618)	156	(13)
Accumulated Net Gain (Loss) from Cash Flow Hedges
Derivative [Line Items]
Accumulated Other Comprehensive (Loss) Income	(6)	(7)	(7)
Accumulated Net Gain (Loss) from Cash Flow Hedges | Interest Rate Derivatives
Derivative [Line Items]
Accumulated Other Comprehensive (Loss) Income	(1)	(2)	(2)
Accumulated Net Gain (Loss) from Cash Flow Hedges | Commodity derivatives
Derivative [Line Items]
Accumulated Other Comprehensive (Loss) Income	(6)	(6)	(6)
Accumulated Net Gain (Loss) from Cash Flow Hedges | Foreign Currency Derivatives
Derivative [Line Items]
Accumulated Other Comprehensive (Loss) Income	1	1	$ 1
Reclassification out of Accumulated Other Comprehensive Income
Derivative [Line Items]
Accumulated Other Comprehensive (Loss) Income	1
Reclassification out of Accumulated Other Comprehensive Income | Interest Rate Derivatives
Derivative [Line Items]
Accumulated Other Comprehensive (Loss) Income	1
Reclassification out of Accumulated Other Comprehensive Income | Commodity derivatives
Derivative [Line Items]
Accumulated Other Comprehensive (Loss) Income	0
Reclassification out of Accumulated Other Comprehensive Income | Foreign Currency Derivatives
Derivative [Line Items]
Accumulated Other Comprehensive (Loss) Income	0
Cash Flow Hedging [Member]
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	0	0
Cash Flow Hedging [Member] | Interest Rate Derivatives
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	0	0
Cash Flow Hedging [Member] | Commodity derivatives
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	0	0
Cash Flow Hedging [Member] | Foreign Currency Derivatives
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ 0	$ 0

Risk Management and Hedging A_7

Risk Management and Hedging Activities - Schedule of Changes in Derivative Instruments not Designated as Hedging Instruments (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative [Line Items]
Trading and marketing (losses) gains, net	$ (618)	$ 156	$ (13)
Derivative Assets Not Designated As Hedging Instruments | Commodity derivatives
Derivative [Line Items]
Realized gains	(493)	101	65
Unrealized gains (losses)	(125)	55	(78)
Trading and marketing (losses) gains, net	$ (618)	$ 156	$ (13)

Risk Management and Hedging A_8

Risk Management and Hedging Activities - Schedule of Net Long or Short Positions Expected to be Realized (Detail)	12 Months Ended
	Dec. 31, 2021MMBTUbbl	Dec. 31, 2020MMBTUbbl
Crude Oil
Net (Short) Position, Volume [Abstract]
Net (Short) Position (Bbls), Year One | bbl	(1,133,000)	(1,969,000)
Net (Short) Position (Bbls), Year Two | bbl	(446,000)	(214,000)
Net (Short) Position (Bbls), Year Three | bbl	0	0
Net (Short) Position (Bbls), Year Four | bbl	0	0
Net Long (Short) Position (Bbls), Year Five | bbl	0	0
Natural Gas [Member]
Net Long (Short) Position, MMBtu [Abstract]
Net (Short) Long Position (MMBtu), Year One | MMBTU	(76,565,200)	(69,887,800)
Net (Short) Long Position (MMBtu), Year Two | MMBTU	912,500	(36,500,000)
Net Long Position (MMBtu), Year Three | MMBTU	0	0
Net Long Position (MMBtu), Year Four | MMBTU	0	0
Net Long Position (MMBtu), Year Five | MMBTU	0	0
Natural Gas Liquids
Net (Short) Position, Volume [Abstract]
Net (Short) Position (Bbls), Year One | bbl	(5,080,635)	(9,857,339)
Net (Short) Position (Bbls), Year Two | bbl	(1,344,000)	(1,422,842)
Net (Short) Position (Bbls), Year Three | bbl	(1,455,000)	(1,440,000)
Net (Short) Position (Bbls), Year Four | bbl	(1,440,000)	(1,440,000)
Net Long (Short) Position (Bbls), Year Five | bbl	(1,440,000)	(1,320,000)
Natural Gas Basis Swaps
Net Long (Short) Position, MMBtu [Abstract]
Net (Short) Long Position (MMBtu), Year One | MMBTU	(7,015,000)	(7,130,000)
Net (Short) Long Position (MMBtu), Year Two | MMBTU	(830,000)	10,950,000
Net Long Position (MMBtu), Year Three | MMBTU	(2,280,000)	3,650,000
Net Long Position (MMBtu), Year Four | MMBTU	9,530,000	2,140,000
Net Long Position (MMBtu), Year Five | MMBTU	535,000	1,825,000

Partnership Equity and Distri_3

Partnership Equity and Distributions - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Partnership Equity And Distribution [Line Items]
Common unitholders, units issued (in shares)	208,373,672	208,351,528
Total Cash Distribution	$ 384	$ 465	$ 677
DCP Midstream LP | DCP Midstream, LLC
Partnership Equity And Distribution [Line Items]
Ownership interest percentage by parent	57.00%
Equity Distribution Agreement [Member]
Partnership Equity And Distribution [Line Items]
Offer Value Of Common Stock Unit Remaining Available For Sale	$ 750

Partnership Equity and Distri_4

Partnership Equity and Distributions - Cash Distribution (Detail) - USD ($) $ / shares in Units, $ in Millions	Dec. 15, 2021	Nov. 12, 2021	Oct. 15, 2021	Sep. 15, 2021	Aug. 13, 2021	Jul. 15, 2021	Jun. 15, 2021	May 14, 2021	Apr. 15, 2021	Mar. 15, 2021	Feb. 12, 2021	Jan. 15, 2021	Dec. 15, 2020	Nov. 13, 2020	Oct. 15, 2020	Sep. 15, 2020	Aug. 14, 2020	Jul. 15, 2020	Jun. 15, 2020	May 15, 2020	Apr. 15, 2020	Mar. 16, 2020	Feb. 14, 2020	Jan. 15, 2020	Dec. 16, 2019	Nov. 14, 2019	Oct. 15, 2019	Sep. 16, 2019	Aug. 14, 2019	Jul. 15, 2019	Jun. 17, 2019	May 15, 2019	Apr. 15, 2019	Mar. 15, 2019	Feb. 14, 2019	Jan. 15, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Distribution Made to Limited Partner [Line Items]
Total Cash Distribution																																					$ 384	$ 465	$ 677
Series A Preferred Limited Partners [Member]
Distribution Made to Limited Partner [Line Items]
Preferred Limited Partnership Distribution; Distribution Amount Paid	$ 36.8750						$ 36.8750						$ 36.8750						$ 36.8750						$ 36.8750						$ 36.8750
Total Cash Distribution	$ 19						$ 18						$ 19						$ 18						$ 19						$ 18						37	37	37
Series B Preferred Limited Partners [Member]
Distribution Made to Limited Partner [Line Items]
Preferred Limited Partnership Distribution; Distribution Amount Paid	$ 0.4922			$ 0.4922			$ 0.4922			$ 0.4922			$ 0.4922			$ 0.4922			$ 0.4922			$ 0.4922			$ 0.4922			$ 0.4922			$ 0.4922			$ 0.4922
Total Cash Distribution	$ 3			$ 4			$ 3			$ 3			$ 4			$ 3			$ 3			$ 3			$ 4			$ 3			$ 3			$ 3			13	13	13
Series C Preferred Limited Partners [Member]
Distribution Made to Limited Partner [Line Items]
Preferred Limited Partnership Distribution; Distribution Amount Paid			$ 0.4969			$ 0.4969			$ 0.4969			$ 0.4969			$ 0.4969			$ 0.4969			$ 0.4969			$ 0.4969			$ 0.4969			$ 0.4969			$ 0.4969			$ 0.5576
Total Cash Distribution			$ 3			$ 2			$ 2			$ 2			$ 2			$ 3			$ 2			$ 2			$ 2			$ 3			$ 2			$ 2	9	9	9
Limited Partners
Distribution Made to Limited Partner [Line Items]
Per Unit Distribution (in dollars per share)		$ 0.39			$ 0.39			$ 0.39			$ 0.39			$ 0.39			$ 0.39			$ 0.39			$ 0.78			$ 0.78			$ 0.78			$ 0.78			$ 0.78
Total Cash Distribution		$ 81			$ 81			$ 82			$ 81			$ 81			$ 82			$ 81			$ 162			$ 155			$ 154			$ 155			$ 154		$ 325	$ 406	$ 447

Equity-Based Compensation (Deta

Equity-Based Compensation (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Strategic Performance Units (SPUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(54,641)	(76,183)	(40,348)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	173,171	141,613	83,054
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Measurement Date Fair Value, Expected to Vest	$ 27.48
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	21.35	$ 26.52	$ 33.02	$ 43.33
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	19.44	23.71	30.60
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	21.32	27.45	34.95
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	30.60	$ 36.23	$ 56.80
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Measurement Date Fair Value, Ending Balance	27.48
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Expected to Vest	$ 21.35
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value	$ 7	$ 4	$ 6
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Share-based Liabilities Paid	$ 4	$ 6	$ 9
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Expected to Vest	481,926
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	524,909	429,261	350,357	251,319
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	323,460	296,700	222,440
Strategic Performance Units (SPUs) | Two-Thousand And Sixteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	120.00%
Strategic Performance Units (SPUs) | Two Thousand And Seventeen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	152.00%
Strategic Performance Units (SPUs) | Two Thousand And Eighteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	150.00%
Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(221,480)	(78,320)	(43,170)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	362,116	123,817	171,881
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Measurement Date Fair Value, Expected to Vest	$ 22.80
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	20.99	$ 22.33	$ 33.35	$ 42.55
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	21.64	20.07	30.52
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	20.43	22.99	34.14
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	24.88	$ 36.25	$ 40.92
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Measurement Date Fair Value, Ending Balance	22.80
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Expected to Vest	$ 20.98
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value	$ 5	$ 3	$ 6
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Share-based Liabilities Paid	$ 3	$ 6	$ 5
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Expected to Vest	523,046
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	587,022	767,488	298,585	231,706
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	403,130	671,040	281,930

Fair Value of Unvested Unit-bas

Fair Value of Unvested Unit-based Awards (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Strategic Performance Units (SPUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting Period (years)	3 years
Unrecognized Compensation Expense at December 31, 2019 (millions)	$ 7
Weighted-Average Remaining Vesting (years)	2 years
Strategic Performance Units (SPUs) | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Estimated Forfeiture Rate	0.00%
Strategic Performance Units (SPUs) | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Estimated Forfeiture Rate	11.00%
Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense at December 31, 2019 (millions)	$ 7
Weighted-Average Remaining Vesting (years)	1 year
Phantom Share Units (PSUs) | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting Period (years)	1 year
Estimated Forfeiture Rate	0.00%
Phantom Share Units (PSUs) | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting Period (years)	3 years
Estimated Forfeiture Rate	11.00%

Equity-Based Compensation - Add

Equity-Based Compensation - Additional Information (Details) - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Payment Arrangement [Abstract]
Share-based compensation expense	$ 20	$ 11	$ 14
Common Units Authorized, in Shares	900

Benefits (Details)

Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Contribution Plan Disclosure [Line Items]
Defined contribution cost	$ 24	$ 26	$ 31
Defined Contribution Plan, Employer Matching Contribution, Percent of Match	6.00%
Automatic enrollment percentage	6.00%
Minimum
Defined Contribution Plan Disclosure [Line Items]
Defined Contribution Plan, Employer Discretionary Contribution, Percentage	4.00%
Maximum
Defined Contribution Plan Disclosure [Line Items]
Defined Contribution Plan, Employer Discretionary Contribution, Percentage	7.00%

Net Income or Loss per Limite_2

Net Income or Loss per Limited Partner Unit Additional Detail (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Earnings Per Share [Abstract]
Weighted Average Number Diluted Shares Outstanding Adjustment	208,600,058	208,338,544	153,116,233
Net Income (Loss), Per Outstanding Limited Partnership Unit, Basic, Net of Tax	$ 1.59	$ (1.75)	$ (1.05)
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	233,804	0	0
Weighted Average Number of Shares Outstanding, Basic	208,366,254	208,338,544	153,116,233
Net Income (Loss) Allocated to Limited Partners	$ 332	$ (365)	$ (160)
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount		304,270

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Current State Tax Expense (Benefit)	$ (1)	$ 0	$ (1)
Deferred State Tax Expense (Benefit)	(5)	0	2
Income tax expense	(6)	0	$ 1
Deferred income taxes	$ 34	$ 30

Restructuring (Details)

Restructuring (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Restructuring Cost and Reserve [Line Items]
Restructuring costs	$ 0	$ 9	$ 11
Restructuring and Related Cost, Number of Positions Eliminated, Inception to Date Percent		15.00%
Restructuring and Related Cost, Expected Cost		$ 9

Business Segments - Segment Inf

Business Segments - Segment Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Segment Reporting Information [Line Items]
Total operating revenues	$ 10,707	$ 6,302	$ 7,625
Gross margin	1,442	1,559	1,603
Operating and maintenance expense	(659)	(607)	(728)
Depreciation and amortization expense	(364)	(376)	(404)
General and administrative expense	(223)	(253)	(275)
Asset Impairments	(31)	(746)	(247)
Other expense, net	5	(15)	(8)
Loss on sale of assets, net	(5)	0	(80)
Restructuring Costs	0	(9)	(11)
Earnings from unconsolidated affiliates	535	447	474
Interest expense, net	(299)	(302)	(304)
Income tax expense	(6)	0	1
Net income	395	(302)	21
Net income attributable to noncontrolling interests	(4)	(4)	(4)
Net income attributable to partners	391	(306)	17
Non-cash derivative mark-to-market	(125)	55	(78)
Non-cash lower of cost or net realizable value adjustment	0	6	10
Capital expenditures	108	160	519
Investments in unconsolidated affiliates, net	5	101	450
Logistics and Marketing
Segment Reporting Information [Line Items]
Total operating revenues	9,734	5,530	6,856
Gathering and Processing
Segment Reporting Information [Line Items]
Total operating revenues	6,894	3,479	4,319
Operating Segments | Logistics and Marketing
Segment Reporting Information [Line Items]
Total operating revenues	9,734	5,530	4,319
Gross margin	138	333	254
Operating and maintenance expense	(38)	(36)	(664)
Depreciation and amortization expense	(12)	(13)	(355)
General and administrative expense	(6)	(7)	(23)
Asset Impairments	(13)	0	(35)
Other expense, net	6	(10)	(5)
Loss on sale of assets, net	2		(10)
Restructuring Costs		0	0
Earnings from unconsolidated affiliates	519	510	6
Interest expense, net	0	0	0
Income tax expense	0		0
Net income	596	777	605
Net income attributable to noncontrolling interests	0	0	(4)
Net income attributable to partners	596	777	605
Non-cash derivative mark-to-market	(19)	78	(49)
Capital expenditures	7	4	474
Investments in unconsolidated affiliates, net	5	101	0
Operating Segments | Gathering and Processing
Segment Reporting Information [Line Items]
Total operating revenues	6,894	3,479	6,856
Gross margin	1,304	1,226	1,349
Operating and maintenance expense	(603)	(554)	(42)
Depreciation and amortization expense	(325)	(333)	(19)
General and administrative expense	(15)	(22)	(8)
Asset Impairments	(18)	(746)	(212)
Other expense, net	(1)	(3)	(3)
Loss on sale of assets, net	(7)		(70)
Restructuring Costs		0	0
Earnings from unconsolidated affiliates	16	(63)	468
Interest expense, net	0	0	0
Income tax expense	0		0
Net income	351	(495)	26
Net income attributable to noncontrolling interests	(4)	(4)	0
Net income attributable to partners	347	(499)	22
Non-cash derivative mark-to-market	(106)	(23)	(29)
Non-cash lower of cost or net realizable value adjustment		0	0
Capital expenditures	93	140	29
Investments in unconsolidated affiliates, net	0	0	450
Other
Segment Reporting Information [Line Items]
Total operating revenues	0	0	0
Gross margin	0	0	0
Operating and maintenance expense	(18)	(17)	(22)
Depreciation and amortization expense	(27)	(30)	(30)
General and administrative expense	(202)	(224)	(244)
Asset Impairments	0	0	0
Other expense, net	0	(2)	0
Loss on sale of assets, net	0		0
Restructuring Costs		(9)	(11)
Earnings from unconsolidated affiliates	0	0	0
Interest expense, net	(299)	(302)	(304)
Income tax expense	(6)		(1)
Net income	(552)	(584)	(610)
Net income attributable to noncontrolling interests	0	0	0
Net income attributable to partners	(552)	(584)	(610)
Non-cash derivative mark-to-market	0	0	0
Non-cash lower of cost or net realizable value adjustment		0	0
Capital expenditures	8	16	16
Investments in unconsolidated affiliates, net	0	0	0
Eliminations
Segment Reporting Information [Line Items]
Total operating revenues	(5,921)	(2,707)	(3,550)
Gross margin	0	0	0
Operating and maintenance expense		0	0
Depreciation and amortization expense	0	0	0
General and administrative expense	0	0	0
Asset Impairments		0	0
Other expense, net		0	0
Restructuring Costs		0	0
Earnings from unconsolidated affiliates	0	0	0
Interest expense, net	0	0	0
Income tax expense	0		0
Net income	0	0	0
Net income attributable to noncontrolling interests	0	0	0
Net income attributable to partners	0	0	0
Non-cash derivative mark-to-market		0	0
Non-cash lower of cost or net realizable value adjustment	0	0	0
Capital expenditures	0	0	0
Investments in unconsolidated affiliates, net	$ 0	$ 0	$ 0

Business Segments - Segment Ass

Business Segments - Segment Assets (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting, Asset Reconciling Item [Line Items]
Segment long-term assets	$ 11,631	$ 11,949
Current assets	1,749	1,008
Total assets	13,380	12,957
Operating Segments | Logistics and Marketing
Segment Reporting, Asset Reconciling Item [Line Items]
Segment long-term assets	3,887	3,929
Operating Segments | Gathering and Processing
Segment Reporting, Asset Reconciling Item [Line Items]
Segment long-term assets	7,515	7,788
Other
Segment Reporting, Asset Reconciling Item [Line Items]
Segment long-term assets	$ 229	$ 232

Statement of Cash Flows, Supp_2

Statement of Cash Flows, Supplemental Disclosures (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract]
Income Taxes Paid, Net	$ 3	$ 3	$ 3
Property, plant and equipment acquired with accounts payable and accrued liabilities	10	7	45
Property, Plant and Equipment, Other Increase (Decrease)	(9)	(3)	(2)
Right-of-Use Assets Obtained in Exchange for Operating and Finance Lease Liabilities	48	18	82
Cash paid for interest, net of amounts capitalized	297	283	258
Cumulative effect of Implementation of Topic 842	$ 0	$ 0	$ 84

Other Income and Expenses (Deta

Other Income and Expenses (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Other Income and Expenses [Abstract]
Operating Income (Loss)	$ 165	$ (447)	$ (150)
Net Income (Loss) Attributable to Parent	391	(306)	17
Net income attributable to noncontrolling interests	(4)	(4)	(4)
Net (loss) income	395	(302)	21
Net Income (Loss) Allocated to Limited Partners	$ 332	$ (365)	$ (160)
Net income per limited partner unit — basic and diluted	$ 1.59	$ (1.75)	$ (1.05)
Total operating revenues	$ 10,707	$ 6,302	$ 7,625

Condensed Consolidating Financi

Condensed Consolidating Financial Information - Condensed Consolidating Balance Sheets (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
ASSETS
Cash and cash equivalents	$ 1	$ 52	$ 1
Inventories	77	38
Total current assets	1,749	1,008
Property, plant and equipment, net	7,701	7,993
Investments in unconsolidated affiliates	3,578	3,641
Total assets	13,380	12,957
LIABILITIES AND EQUITY
Current debt	355	505
Long-term debt	5,078	5,119
Total liabilities	7,504	7,096
Equity:
Accumulated other comprehensive loss	(6)	(7)
Total partners’ equity	5,851	5,834
Noncontrolling interests	25	27
Total equity	5,876	5,861	$ 6,633	$ 7,297
Total liabilities and equity	$ 13,380	$ 12,957

Condensed Consolidating Finan_2

Condensed Consolidating Financial Information - Condensed Consolidating Statements of Operations (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating revenues:
Trading and marketing gains (losses), net	$ (618)	$ 156	$ (13)
Total operating revenues	10,707	6,302	7,625
Operating and maintenance expense	659	607	728
Depreciation and amortization expense	364	376	404
General and administrative expense	223	253	275
Asset Impairment	31	746	247
Loss on sale of assets, net	5	0	80
Restructuring costs	0	9	11
Other income (expense)	(5)	15	8
Costs and Expenses	10,542	6,749	7,775
Operating (loss) income	165	(447)	(150)
Interest Expense	(299)	(302)	(304)
Earnings from unconsolidated affiliates	535	447	474
(Loss) income before income taxes	401	(302)	20
Income tax expense	(6)	0	1
Net income	395	(302)	21
Net income attributable to noncontrolling interests	(4)	(4)	(4)
Net income attributable to partners	391	(306)	17
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	1	0	1
Other comprehensive income	1	0	1
Total comprehensive income	396	(302)	22
Total comprehensive income attributable to noncontrolling interests	(4)	(4)	(4)
Total comprehensive income attributable to partners	392	(306)	18
Consolidating Adjustments
Operating revenues:
Total operating revenues	(5,921)	(2,707)	(3,550)
Operating and maintenance expense		0	0
Depreciation and amortization expense	0	0	0
General and administrative expense	0	0	0
Asset Impairment		0	0
Restructuring costs		0	0
Other income (expense)		0	0
Interest Expense	0	0	0
Earnings from unconsolidated affiliates	0	0	0
Income tax expense	0		0
Net income	0	0	0
Net income attributable to noncontrolling interests	0	0	0
Net income attributable to partners	0	0	0
Transportation, Processing and Other [Member]
Operating revenues:
Sales of natural gas, NGLs and condensate	$ 539	$ 455	$ 439

Condensed Consolidating Finan_3

Condensed Consolidating Financial Information - Condensed Consolidating Statement of Comprehensive Income (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Condensed Financial Statements, Captions [Line Items]
Net (loss) income	$ 395	$ (302)	$ 21
Other comprehensive income (loss):
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	1	0	1
Other comprehensive income	1	0	1
Total comprehensive income	396	(302)	22
Total comprehensive income attributable to noncontrolling interests	(4)	(4)	(4)
Total comprehensive income attributable to partners	$ 392	$ (306)	$ 18

Condensed Consolidating Finan_4

Condensed Consolidating Financial Information - Condensed Consolidating Statements of Cash Flows (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
OPERATING ACTIVITIES
Net cash (used in) provided by operating activities	$ 646	$ 1,099	$ 859
INVESTING ACTIVITIES:
Capital expenditures	(108)	(160)	(519)
Investments in unconsolidated affiliates	(5)	(101)	(450)
Proceeds from sale of assets	3	2	209
Net cash used in investing activities	(110)	(259)	(760)
FINANCING ACTIVITIES:
Proceeds from debt	4,721	4,407	5,971
Payments of debt	4,916	4,713	5,372
Distribution Made to Limited Partner, Cash Distributions Paid	59	59	59
Distributions to limited partners and general partner	(325)	(406)	(618)
GP and IDR Conversion Costs	0	0	(3)
Proceeds from (Payments for) Other Financing Activities	0	(1)	0
Net cash provided by (used in) financing activities	(591)	(785)	(99)
Cash and cash equivalents, beginning of period	52	1
Cash and cash equivalents, end of period	$ 1	$ 52	$ 1

Subsequent Events - Additional

Subsequent Events - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions

Apr. 15, 2022

Apr. 01, 2022

Mar. 15, 2022

Mar. 01, 2022

Feb. 14, 2022

Feb. 04, 2022

Jan. 24, 2022

Dec. 15, 2021

Oct. 15, 2021

Sep. 15, 2021

Jul. 15, 2021

Jun. 15, 2021

Apr. 15, 2021

Mar. 15, 2021

Jan. 15, 2021

Dec. 15, 2020

Oct. 15, 2020

Sep. 15, 2020

Jul. 15, 2020

Jun. 15, 2020

Apr. 15, 2020

Mar. 16, 2020

Jan. 15, 2020

Dec. 16, 2019

Oct. 15, 2019

Sep. 16, 2019

Jul. 15, 2019

Jun. 17, 2019

Apr. 15, 2019

Mar. 15, 2019

Jan. 15, 2019

Dec. 31, 2020

Subsequent Event [Line Items]

Restructuring and Related Cost, Number of Positions Eliminated, Inception to Date Percent

15.00%

Restructuring and Related Cost, Expected Cost

$ 9

Series A Preferred Limited Partners [Member]

Subsequent Event [Line Items]

Preferred Limited Partnership Unit; Distribution Amount Declared

$ 36.8750

$ 36.8750

$ 36.8750

$ 36.8750

$ 36.8750

$ 36.8750

Series B Preferred Limited Partners [Member]

Subsequent Event [Line Items]

Preferred Limited Partnership Unit; Distribution Amount Declared

$ 0.4922

$ 0.4922

$ 0.4922

$ 0.4922

$ 0.4922

$ 0.4922

$ 0.4922

$ 0.4922

$ 0.4922

$ 0.4922

$ 0.4922

$ 0.4922

Series C Preferred Limited Partners [Member]

Subsequent Event [Line Items]

Preferred Limited Partnership Unit; Distribution Amount Declared

$ 0.4969

$ 0.4969

$ 0.4969

$ 0.4969

$ 0.4969

$ 0.4969

$ 0.4969

$ 0.4969

$ 0.4969

$ 0.4969

$ 0.4969

$ 0.5576

Subsequent Event [Member]

Subsequent Event [Line Items]

Distribution Made to Limited Partner, Distributions Declared, Per Unit

$ 0.39

Distribution Made to Limited Partner, Date of Record

Feb. 4, 2022

Distribution Made to Limited Partner, Distribution Date

Feb. 14, 2022

Subsequent Event [Member] | Series B Preferred Limited Partners [Member]

Subsequent Event [Line Items]

Distribution Made to Common Unitholders, Declaration Date

Jan. 24, 2022

Preferred Limited Partner Distribution: Record Date

Mar. 1, 2022

Preferred Limited Partnership Distribution; Distribution Date

Mar. 15, 2022

Preferred Limited Partnership Unit; Distribution Amount Declared

$ 0.4922

Subsequent Event [Member] | Series C Preferred Limited Partners [Member]

Subsequent Event [Line Items]

Preferred Limited Partner Distribution: Record Date

Apr. 1, 2022

Preferred Limited Partnership Distribution; Distribution Date

Apr. 15, 2022

Preferred Limited Partnership Unit; Distribution Amount Declared

$ 0.4969