0001591763-21-000041 | 10-Q | XBRL Viewer | Enable Midstream Partners LP

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Document and Entity Information - shares	3 Months Ended
Document and Entity Information - shares	Mar. 31, 2021	Apr. 16, 2021
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2021
Document Transition Report	false
Entity File Number	1-36413
Entity Registrant Name	ENABLE MIDSTREAM PARTNERS, LP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	72-1252419
Entity Address, Address Line One	499 West Sheridan Avenue,
Entity Address, Address Line Two	Suite 1500
Entity Address, City or Town	Oklahoma City,
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	73102
City Area Code	405
Local Phone Number	525-7788
Title of 12(b) Security	Common Units Representing Limited Partner Interests
Trading Symbol	ENBL
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity Filer Category	Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q1
Entity Central Index Key	0001591763
Entity Common Stock, Shares Outstanding		435,866,139
Current Fiscal Year End Date	--12-31

Condensed Consolidated Statements of Income (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Revenues (including revenues from affiliates (Note 13)):
Total Revenues	$ 970	$ 648
Cost and Expenses (including expenses from affiliates (Note 13)):
Cost of natural gas and natural gas liquids (excluding depreciation and amortization shown separately)	519	226
Operation and maintenance	84	102
General and administrative	37	24
Depreciation and amortization	106	104
Impairments of property, plant and equipment and goodwill (Note 7)	0	28
Taxes other than income tax	18	18
Total Cost and Expenses	764	502
Operating Income	206	146
Other Income (Expense):
Interest expense	(42)	(47)
Equity in earnings (losses) of equity method affiliate, net	1	6
Total Other Expense	(41)	(41)
Income Before Income Tax
Income Before Income Tax	165	105
Income tax benefit	0	0
Net Income
Net Income	165	105
Less: Net income (loss) attributable to noncontrolling interest
Less: Net income (loss) attributable to noncontrolling interest	1	(7)
Net Income Attributable to Limited Partners
Net Income Attributable to Limited Partners	164	112
Less: Series A Preferred Unit distributions (Note 6)
Less: Series A Preferred Unit distributions (Note 6)	9	9
Net Income Attributable to Common Units (Note 5)
Net Income Attributable to Common Units (Note 5)	155	103
Common Unit [Member]
Net Income Attributable to Common Units (Note 5)
Net Income Attributable to Common Units (Note 5)	$ 155	$ 103
Basic and Diluted earnings per unit and weighted average number of units outstanding
Basic and diluted earnings per unit (Note 5)	$ 0.35	$ 0.24
Diluted	$ 0.33	$ 0.19
Product
Revenues (including revenues from affiliates (Note 13)):
Total Revenues	$ 627	$ 288
Natural Gas, Gathering, Transportation, Marketing and Processing
Revenues (including revenues from affiliates (Note 13)):
Total Revenues	$ 343	$ 360

Condensed Consolidated Statement of Comprehensive Income Statement (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Statement of Comprehensive Income [Abstract]
Net income	$ 165	$ 105
Other comprehensive income (loss):
Change in fair value of interest rate derivative instruments	0	(6)
Reclassification of interest rate derivative losses to net income	1	0
Other comprehensive income (loss)	1	(6)
Comprehensive income	166	99
Less: Comprehensive income (loss) attributable to noncontrolling interest	1	(7)
Comprehensive income attributable to Limited Partners	$ 165	$ 106

- Definition

Amount after tax of increase (decrease) in equity from transactions and other events and circumstances from net income (loss) and other comprehensive income (loss), attributable to noncontrolling interests. Excludes changes in equity resulting from investments by owners and distributions to owners.

+ References + Details

- Definition

Amount after tax of increase (decrease) in equity from transactions and other events and circumstances from net income and other comprehensive income. Excludes changes in equity resulting from investments by owners and distributions to owners.

+ References + Details

- Definition

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

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+ Details

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Current Assets:
Cash and cash equivalents	$ 32	$ 3
Accounts receivable, net of allowance for doubtful accounts (Note 1)	284	248
Accounts receivable—affiliated companies	13	15
Inventory	44	42
Gas imbalances	49	42
Other current assets, net of allowance for doubtful accounts (Note 1)	27	31
Total current assets	449	381
Property, Plant and Equipment:
Property, plant and equipment	13,287	13,220
Less: Accumulated depreciation and amortization	2,633	2,555
Property, plant and equipment, net	10,654	10,665
Other Assets:
Intangible assets, net	523	539
Investment in equity method affiliate	73	76
Other	65	68
Total other assets	661	683
Total Assets	11,764	11,729
Current Liabilities:
Accounts payable	158	149
Accounts payable—affiliated companies	1	2
Current portion of long-term debt	800	0
Short-term debt	214	250
Taxes accrued	26	34
Gas imbalances	13	19
Other	122	128
Total current liabilities	1,334	582
Other Liabilities:
Accumulated deferred income taxes, net	4	5
Regulatory liabilities	26	25
Other	67	71
Total other liabilities	97	101
Long-Term Debt	3,152	3,951
Commitments and Contingencies (Note 14)
Partners’ Equity:
Series A Preferred Units (14,520,000 issued and outstanding at March 31, 2021 and December 31, 2020)	362	362
Common Units (435,846,766 issued and outstanding at March 31, 2021 and 435,549,892 issued and outstanding at December 31, 2020)	6,798	6,713
Accumulated other comprehensive loss	(5)	(6)
Noncontrolling interest	26	26
Total Partners’ Equity	7,181	7,095
Total Liabilities and Partners’ Equity	$ 11,764	$ 11,729

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - shares	Mar. 31, 2021	Dec. 31, 2020
Common Unit [Member]
Common units issued	435,846,766	435,549,892
Common units outstanding	435,846,766	435,549,892
Series A Preferred Units [Member]
Preferred Units, Issued	14,520,000	14,520,000
Preferred Units, Outstanding	14,520,000	14,520,000

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Cash Flows from Operating Activities:
Net income	$ 165	$ 105
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	106	104
Impairments of property, plant and equipment and goodwill	0	28
Net loss on sale/retirement of assets	0	1
Equity in earnings of equity method affiliate	(1)	(6)
Return on investment in equity method affiliate	1	6
Equity-based compensation	4	4
Amortization of debt costs and discount	1	0
Changes in other assets and liabilities:
Accounts receivable, net	(36)	52
Accounts receivable—affiliated companies	2	8
Inventory	(2)	3
Gas imbalance assets	(7)	(1)
Other current assets, net	2	(6)
Other assets	2	1
Accounts payable	11	(59)
Accounts payable—affiliated companies	(1)	1
Gas imbalance liabilities	(6)	(2)
Other current liabilities	(14)	(35)
Other liabilities	(4)	(4)
Net cash provided by operating activities	223	200
Cash Flows from Investing Activities:
Capital expenditures	(80)	(54)
Proceeds from sale of assets	1	0
Return of investment in equity method affiliate	3	4
Other, net	1	2
Net cash used in investing activities	(75)	(48)
Cash Flows from Financing Activities:
Decrease in short-term debt	(36)	(45)
Repayment of long-term debt	0	(250)
Proceeds from Revolving Credit Facility	0	340
Repayment of Revolving Credit Facility	0	(40)
Distributions to common unitholders	(72)	(144)
Distributions to preferred unitholders	(9)	(9)
Distributions to non-controlling interests	(1)	(3)
Cash paid for employee equity-based compensation	(1)	(1)
Net cash used in financing activities	(119)	(152)
Net Increase in Cash, Cash Equivalents and Restricted Cash	29	0
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	3	4
Cash, Cash Equivalents and Restricted Cash at End of Period	$ 32	$ 4

Condensed Consolidated Statements of Partners' Equity (Unaudited) - USD ($) shares in Millions, $ in Millions	Total	Cumulative Effect, Period of Adoption, Adjustment	Noncontrolling Interest [Member]	Series A Preferred Units [Member] Preferred Units	Common Unit [Member] Partners' Capital	Common Unit [Member] Partners' Capital Cumulative Effect, Period of Adoption, Adjustment	AOCI Attributable to Parent
Balance, beginning of period at Dec. 31, 2019	$ 7,409	$ (3)	$ 37	$ 362	$ 7,013	$ (3)	$ (3)
Balance, beginning of period, units at Dec. 31, 2019				15	435
Changes in Partners' Capital
Net Income	105		(7)	$ 9	$ 103
Other comprehensive loss	(6)						(6)
Partners' Capital Account, Distributions	(156)		(3)	(9)	(144)
Partners' Capital Account, Unit-based Compensation, Net of Taxes	3				$ 3
Equity-based compensation, net of units for employee taxes, units					0
Balance, end of period at Mar. 31, 2020	7,352		27	$ 362	$ 6,972		(9)
Balance, end of period, units at Mar. 31, 2020				15	435
Balance, beginning of period at Dec. 31, 2020	7,095		26	$ 362	$ 6,713		(6)
Balance, beginning of period, units at Dec. 31, 2020				15	435
Changes in Partners' Capital
Net Income	165		1	$ 9	$ 155
Other comprehensive loss	1						1
Partners' Capital Account, Distributions	(82)		(1)	(9)	(72)
Partners' Capital Account, Unit-based Compensation, Net of Taxes	2				$ 2
Equity-based compensation, net of units for employee taxes, units					1
Balance, end of period at Mar. 31, 2021	$ 7,181		$ 26	$ 362	$ 6,798	$ 0	$ (5)
Balance, end of period, units at Mar. 31, 2021				15	436

- Definition

Amount after tax of income (loss) from continuing operations including portion attributable to the noncontrolling interest.

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+ Details

Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Summary of Significant Accounting Policies

Organization

Enable Midstream Partners, LP (the Partnership) is a Delaware limited partnership whose assets and operations are organized into two reportable segments: (i) gathering and processing and (ii) transportation and storage. Our gathering and processing segment primarily provides natural gas gathering and processing services to our producer customers and crude oil, condensate and produced water gathering services to our producer and refiner customers. The transportation and storage segment provides interstate and intrastate natural gas pipeline transportation and storage services primarily to our producer, power plant, LDC and industrial end-user customers. Our natural gas gathering and processing assets are primarily located in Oklahoma, Texas, Arkansas and Louisiana and serve natural gas production in the Anadarko, Arkoma and Ark-La-Tex Basins. Crude oil gathering assets are located in Oklahoma and serve crude oil production in the SCOOP and STACK plays of the Anadarko Basin and in North Dakota and serve crude oil production in the Bakken Shale formation of the Williston Basin. The Partnership’s natural gas transportation and storage assets consist primarily of an interstate pipeline system extending from western Oklahoma and the Texas Panhandle to Louisiana, an interstate pipeline system extending from Louisiana to Illinois, an intrastate pipeline system in Oklahoma, and our investment in SESH, a pipeline extending from Louisiana to Alabama.

CenterPoint Energy and OGE Energy each have 50% of the management interests in Enable GP. Enable GP is the general partner of the Partnership and has no other operating activities. Enable GP is governed by a board made up of two representatives designated by each of CenterPoint Energy and OGE Energy, along with the Partnership’s Chief Executive Officer and three independent board members CenterPoint Energy and OGE Energy mutually agreed to appoint. CenterPoint Energy and OGE Energy also own a 40% and 60% interest, respectively, in the incentive distribution rights held by Enable GP.

As of March 31, 2021, CenterPoint Energy held approximately 53.7% or 233,856,623 of the Partnership’s common units, and OGE Energy held approximately 25.5% or 110,982,805 of the Partnership’s common units. Additionally, CenterPoint Energy holds 14,520,000 Series A Preferred Units. The limited partner interests of the Partnership have limited voting rights on matters affecting the business. As such, limited partners do not have rights to elect the Partnership’s general partner on an annual or continuing basis and may not remove Enable GP, its current general partner, without at least a 75% vote by all unitholders, including all units held by the Partnership’s limited partners, and Enable GP and its affiliates, voting together as a single class.

As of March 31, 2021, the Partnership owned a 50% interest in SESH. See Note 8 for further discussion of SESH. For the three months ended March 31, 2021, the Partnership owned a 50% ownership in Atoka and consolidated Atoka in the accompanying Condensed Consolidated Financial Statements as EOIT acted as the managing member of Atoka and had control over the operations of Atoka. In addition, the Partnership held a 60% interest in ESCP, which is consolidated in the accompanying Condensed Consolidated Financial Statements as EOCS acted as the managing member of ESCP and had control over the operations of ESCP.

Merger Agreement

On February 17, 2021, the Partnership and Energy Transfer announced their entry into a Merger Agreement, whereby the Partnership will be acquired by Energy Transfer in an all-equity transaction, including the assumption of debt and other liabilities. Under the terms of the Merger Agreement, which has been unanimously approved by the Boards of Directors of both companies, Partnership common unitholders will receive 0.8595 of an Energy Transfer common unit for each Partnership common unit. Each of the Partnership’s Series A Preferred Units will be exchanged for 0.0265 Series G preferred units of Energy Transfer. The transaction will also include a $10 million cash payment for the Partnership’s general partner.

Generally, the Merger, including the receipt of equity consideration by common unitholders is expected to be treated as a tax-free transaction subject to certain exceptions as described in a Registration Statement on Form S-4 filed by Energy Transfer. The transaction, which is expected to close in mid-2021, is subject to customary closing conditions. CenterPoint Energy and OGE Energy, who collectively own approximately 79% of the outstanding Partnership common units, delivered their consents to the transaction. The Merger Agreement includes certain customary restrictions on the Partnership until closing of the Merger, such as limitations on distributions, equity issuances, and incurring and prepaying indebtedness. If the Merger does not occur, under certain circumstances, the Partnership may be required to pay Energy Transfer a termination fee of $97.5 million. Until the approval by unitholders and subsequent closing, we must continue to operate the Partnership as a stand-alone company.

Basis of Presentation

The accompanying Condensed Consolidated Financial Statements and related notes of the Partnership have been prepared pursuant to the rules and regulations of the SEC and GAAP. Pursuant to such rules and regulations, certain disclosures normally included in financial statements prepared in accordance with GAAP have been omitted. The accompanying Condensed Consolidated Financial Statements and related notes should be read in conjunction with the Consolidated Financial Statements and related notes included in our Annual Report.

The Condensed Consolidated Financial Statements and the related notes reflect all normal recurring adjustments that are, in the opinion of management, necessary to present fairly the financial position and results of operations for the respective periods. Amounts reported in the Partnership’s Condensed Consolidated Statements of Income are not necessarily indicative of amounts expected for a full-year period due to the effects of, among other things, (a) seasonal fluctuations in demand for energy and energy services, (b) changes in energy commodity prices, (c) timing of maintenance and other expenditures, (d) acquisitions and dispositions of businesses, assets and other interests, and (e) the impact of the ongoing COVID-19 pandemic and the economic effects of the pandemic which have resulted in a substantial decrease in natural gas, NGLs and crude oil prices.

For a description of the Partnership’s reportable segments, see Note 16.

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Sales and Retirements of Assets

On September 23, 2019, the Partnership entered into an agreement to sell its undivided 1/12th interest in the Bistineau Storage Facility in Louisiana for approximately $19 million. On January 27, 2020, FERC approved the sale. The Partnership closed the sale on April 1, 2020. We did not recognize a gain or loss on this transaction.

Depreciation Expense

On March 26, 2020, FERC issued an order approving MRT’s 2018 Rate Case and 2019 Rate Case settlements. As a result of the settlements, the new depreciation rates for MRT have been applied in accordance with the order. The new depreciation rates did not result in a material change in depreciation expense or results of operations.

Accounts Receivable and Allowance for Doubtful Accounts

The Partnership adopted ASU No. 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments” on January 1, 2020. Upon adoption, the Partnership recognized a $3 million cumulative adjustment to Partners’ Equity and a corresponding adjustment to Allowance for doubtful accounts.

Accounts receivable are recorded at the invoiced amount and do not typically bear interest. The determination of the allowance for doubtful accounts requires management to make estimates and judgments regarding our customers’ ability to pay. The allowance for doubtful accounts is determined based primarily upon the historical loss-rate method established for various pools of accounts receivables with similar levels of credit risk. The historical loss-rates are then adjusted, as necessary, based on current conditions and forecast information that could result in future uncollectable amounts. On an ongoing basis, we evaluate our customers’ financial strength and liquidity based on aging of accounts receivable, payment history, and review of other relevant information, including ratings agency credit ratings and alerts, publicly available reports and news releases, and bank and trade references. It is the policy of management to review the outstanding accounts receivable and other receivable balances within other assets at least quarterly, giving consideration to credit losses, the aging of receivables, specific customer circumstances that may impact their ability to pay the amounts due and current and forecast economic conditions over the assets contractual lives. The following table summarizes the required allowance for doubtful accounts.


	March 31, 2021		December 31, 2020

	(In millions)
Accounts receivable	$	4	$	1
Other assets	3		3
Total Allowance for doubtful accounts	$	7	$	4

Inventory

Natural gas inventory is held, through the transportation and storage segment, to provide operational support for pipeline deliveries and to manage leased intrastate storage capacity. Natural gas liquids inventory is held, through the gathering and processing segment, due to timing differences between the production of certain natural gas liquids and ultimate sale to third parties. Natural gas and natural gas liquids inventory is valued using moving average cost and is subsequently recorded at the lower of cost or net realizable value. The Partnership recorded write-downs to net realizable value related to natural gas and natural gas liquids inventory of $1 million and $6 million during the three months ended March 31, 2021 and 2020, respectively.

Impairment of Long-Lived Assets (including Intangible Assets)

The Partnership periodically evaluates long-lived assets, including property, plant and equipment, and specifically identifiable intangibles other than goodwill, when events or changes in circumstances indicate that the carrying value of these assets may not be recoverable. The determination of whether an impairment has occurred is based on an estimate of undiscounted cash flows attributable to the assets, as compared to the carrying value of the assets. For more information, see Note 7.

Impairment of Goodwill

The Partnership assesses its goodwill for impairment annually on October 1st, or more frequently if events or changes in circumstances indicate that the carrying value of goodwill may not be recoverable. Goodwill is assessed for impairment by comparing the fair value of the reporting unit with its book value, including goodwill. The Partnership utilizes the market or income approaches to estimate the fair value of the reporting unit, also giving consideration to the alternative cost approach. Under the market approach, historical and current year forecasted cash flows are multiplied by a market multiple to determine fair value. Under the income approach, anticipated cash flows over a period of years plus a terminal value are discounted to present value using appropriate discount rates. The resulting fair value of the reporting unit is then compared to the carrying amount of the reporting unit and an impairment charge is recorded to goodwill for the difference. The Partnership performs its goodwill impairment testing at the reporting unit, which is one level below the transportation and storage and gathering and processing reportable segment level. For more information, see Note 7.

New Accounting Pronouncements	3 Months Ended
New Accounting Pronouncements	Mar. 31, 2021
Accounting Changes and Error Corrections [Abstract]
New Accounting Pronouncements	New Accounting Pronouncements Reference Rate Reform In March 2020, the FASB issued ASU No. 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting.” This standard provides optional guidance, for a limited time, to ease the potential burden in accounting for or recognizing the effects of reference rate reform on financial reporting. The standard was effective upon issuance and generally can be applied through December 31, 2022. The Partnership adopted ASU 2020-04 during the year ended December 31, 2020. The implementation had no material impact on the Consolidated Financial Statements and related disclosures. In January 2021, the FASB issued ASU No. 2021-01, “Reference Rate Reform (Topic 848): Scope.” This standard clarifies that certain optional expedients and exceptions in ASC 848 for contract modifications and hedge accounting apply to derivatives that are affected by the discounting transition. ASU 2021-01 also amends the expedients and exceptions in ASC 848 to capture the incremental consequences of the scope clarification and to tailor the existing guidance to derivative instruments affected by the discounting transition. ASU 2021-01 was effective upon issuance and generally can be applied through December 31, 2022. The Partnership adopted ASU 2021-01 during three months ended March 31, 2021. The implementation had no material impact on the Condensed Consolidated Financial Statements and related disclosures.

- Definition

The entire disclosure for change in accounting principle. Includes, but is not limited to, nature, reason, and method of adopting amendment to accounting standards or other change in accounting principle.

+ References

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+ Details

Revenue

3 Months Ended

Mar. 31, 2021

Revenue from Contract with Customer [Abstract]

Revenue

Revenues

The following tables disaggregate total revenues by major source from contracts with customers and the gain (loss) on derivative activity for the three months ended March 31, 2021 and 2020.


	Three Months Ended March 31, 2021
	Gathering and Processing		Transportation and Storage		Eliminations		Total

	(In millions)
Revenues:
Product sales:
Natural gas	$	112	$	330	$	(130)	$	312
Natural gas liquids	297		3		(3)		297
Condensate	32		—		—		32
Total revenues from natural gas, natural gas liquids, and condensate	441		333		(133)		641
Loss on derivative activity	(13)		(1)		—		(14)
Total Product sales	$	428	$	332	$	(133)	$	627
Service revenues:
Demand revenues	$	26	$	127	$	—	$	153
Volume-dependent revenues	170		23		(3)		190
Total Service revenues	$	196	$	150	$	(3)	$	343
Total Revenues	$	624	$	482	$	(136)	$	970


	Three Months Ended March 31, 2020
	Gathering and Processing		Transportation and Storage		Eliminations		Total

	(In millions)
Revenues:
Product sales:
Natural gas	$	56	$	73	$	(60)	$	69
Natural gas liquids	172		2		(2)		172
Condensate	27		—		—		27
Total revenues from natural gas, natural gas liquids, and condensate	255		75		(62)		268
Gain on derivative activity	20		—		—		20
Total Product sales	$	275	$	75	$	(62)	$	288
Service revenues:
Demand revenues	$	39	$	142	$	—	$	181
Volume-dependent revenues	163		17		(1)		179
Total Service revenues	$	202	$	159	$	(1)	$	360
Total Revenues	$	477	$	234	$	(63)	$	648

MRT Rate Case Settlements

In June 2018, MRT filed a general NGA rate case (the 2018 Rate Case), and in October 2019, MRT filed a second rate case (the 2019 Rate Case). MRT began collecting the rates proposed in the 2018 Rate Case, subject to refund, on January 1, 2019. On March 26, 2020, FERC issued an order approving settlements filed in the 2018 Rate Case and the 2019 Rate Case. Upon issuance of the order and approval of the settlement of the MRT rate cases, the Partnership recognized $17 million of revenues from amounts previously held in reserve related to transportation and storage services performed in 2019. In May 2020, $21 million previously held in reserve was refunded to customers, which is inclusive of interest.

Accounts Receivable

The following table summarizes the components of accounts receivable, net of allowance for doubtful accounts.


	March 31, 2021		December 31, 2020

	(In millions)
Accounts Receivable:
Customers	$	272	$	245
Contract assets (1)	21		12
Non-customers	4		6
Total Accounts Receivable (2)	$	297	$	263

____________________

(1)Contract assets reflected in Total Accounts Receivable include accrued minimum volume commitments. Contract assets are primarily attributable to revenues associated with estimated shortfall volumes on certain annual minimum volume commitment arrangements. Total Accounts Receivable does not include contract assets related to firm service transportation contracts with tiered rates of $10 million as of March 31, 2021 and $9 million as of December 31, 2020, which are reflected in Other Assets.

(2)Total Accounts Receivable includes Accounts receivable, net of allowance for doubtful accounts and Accounts receivable—affiliated companies.

Contract Liabilities

Our contract liabilities primarily consist of prepayments received from customers for which the good or service has not yet been provided in connection with the prepayment.

The table below summarizes the change in the contract liabilities.


	March 31, 2021		December 31, 2020

	(In millions)
Deferred revenues, beginning of period (1)	$	44	$	48
Amounts recognized in revenues related to the beginning balance	(17)		(25)
Net additions	16		21
Deferred revenues, end of period (1)	$	43	$	44

____________________

(1)Deferred revenues includes deferred revenue—affiliated companies. This amount is included in Other current liabilities and Other long-term liabilities.

The table below summarizes the timing of recognition of these contract liabilities as of March 31, 2021.


	2021		2022		2023		2024		2025 and After
	(In millions)
Deferred revenues (1)	$	20	$	7	$	7	$	7	$	2

____________________

(1)Deferred revenues includes deferred revenue—affiliated companies. This amount is included in Other current liabilities and Other long-term liabilities.

Remaining Performance Obligations

Our remaining performance obligations consist primarily of firm arrangements and minimum volume commitment arrangements. Upon completion of the performance obligations associated with these arrangements, customers are invoiced and revenue is recognized as Service revenues in the Condensed Consolidated Statements of Income.

The table below summarizes the timing of recognition of the remaining performance obligations as of March 31, 2021.


	2021		2022		2023		2024		2025 and After
	(In millions)
Transportation and Storage	$	325	$	393	$	353	$	266	$	959
Gathering and Processing	93		123		121		101		213
Total remaining performance obligations	$	418	$	516	$	474	$	367	$	1,172

- Definition

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
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+ Details

Leases

3 Months Ended

Mar. 31, 2021

Leases [Abstract]

Leases

The table below summarizes the operating leases included in the Condensed Consolidated Balance Sheets.


	Balance Sheet Location	March 31, 2021		December 31, 2020

		(In millions)
Operating lease asset	Other Assets	$	24	$	25
Total right-of-use assets		$	24	$	25

Operating lease liabilities	Other Current Liabilities	$	4	$	4
Operating lease liabilities	Other Liabilities	23		24
Total lease liabilities		$	27	$	28

As of March 31, 2021, all lease obligations outstanding were classified as operating leases. Therefore, all cash flows are reflected in Cash Flows from Operating Activities.

The following table presents the Partnership’s rental costs associated with field equipment and buildings.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Rental Costs:
Field equipment		$	3	$	5
Office space		1		1

As of March 31, 2021, the weighted average remaining lease term is 6.5 years and the weighted average discount rate is 5.49%.

The following table presents the Partnership’s lease cost.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Lease Cost:
Operating lease cost		$	1	$	2
Short-term lease cost		2		3
Variable lease cost		1		1
Total Lease Cost		$	4	$	6

The Partnership recorded no short-term lease costs in the transportation and storage reportable segment during the three months ended March 31, 2021 and 2020. All lease costs were included in the gathering and processing reportable segment.

Under ASC 842, as of March 31, 2021, the Partnership has operating lease obligations expiring at various dates. Undiscounted cash flows for operating lease liabilities are as follows:


	Non-cancellable operating leases

	(In millions)
Year Ending December 31,
2021 - remainder	$	4
2022	5
2023	6
2024	4
2025	3
2026	2
After 2026	6
Total	30
Less: impact of the applicable discount rate	3
Total lease liabilities	$	27

Earnings Per Limited Partner Unit

3 Months Ended

Mar. 31, 2021

Earnings Per Share [Abstract]

Earnings Per Limited Partner Unit

The following table illustrates the Partnership’s calculation of earnings per unit for common units.


	Three Months Ended March 31,
		2021		2020

		(In millions, except per unit data)
Net income		$	165	$	105
Net income (loss) attributable to noncontrolling interest		1		(7)
Series A Preferred Unit distributions		9		9

Net income available to common units		$	155	$	103

Net income allocable to common units		$	155	$	103
Dilutive effect of Series A Preferred Unit distributions		9		9
Diluted net income allocable to common units		$	164	$	112



Basic weighted average number of common units outstanding (1)		438		437
Dilutive effect of Series A Preferred Units		57		144
Dilutive effect of performance units (2)		—		—
Diluted weighted average number of common units outstanding		495		581

Basic and diluted earnings per unit
Basic		$	0.35	$	0.24
Diluted		$	0.33	$	0.19

____________________

(1)Basic weighted average number of outstanding common units includes approximately two million time-based phantom units for each of the three months ended March 31, 2021 and 2020.

(2)The dilutive effect of the performance unit awards was less than $0.01 per unit during the three months ended March 31, 2021 and 2020.

Partners' Equity

3 Months Ended

Mar. 31, 2021

Equity [Abstract]

Partners' Equity

Partners’ Equity

The Partnership Agreement requires that, within 60 days after the end of each quarter, the Partnership distribute all of its available cash (as defined in the Partnership Agreement) to unitholders of record on the applicable record date.

The Partnership paid or has authorized payment of the following cash distributions to common unitholders, as applicable, during 2021 and 2020 (in millions, except for per unit amounts):

Three Months Ended

Record Date

Payment Date

Per Unit Distribution

Total Cash Distribution

March 31, 2021(1)

May 13, 2021

May 25, 2021

0.16525

December 31, 2020

February 22, 2021

March 1, 2021

0.16525

September 30, 2020

November 17, 2020

November 24, 2020

0.16525

June 30, 2020

August 18, 2020

August 25, 2020

0.16525

March 31, 2020

May 19, 2020

May 27, 2020

0.16525

_____________________

(1)The Board of Directors declared a $0.16525 per common unit cash distribution on April 26, 2021, to be paid on May 25, 2021 to common unitholders of record at the close of business on May 13, 2021.

Holders of the Series A Preferred Units receive a quarterly cash distribution on a non-cumulative basis if and when declared by the General Partner, and subject to certain adjustments, equal to an annual rate of 10% on the stated liquidation preference of $25.00 from the date of original issue, February 18, 2016, to, but not including, the five-year anniversary of the original issue date, February 18, 2021. Thereafter, the holders receive a quarterly cash distribution based on a percentage of the stated liquidation preference equal to the sum of the three-month LIBOR plus 8.5%, which was 8.7375% for the relevant days in the three months ended March 31, 2021.

The Partnership paid or has authorized payment of the following cash distributions to holders of the Series A Preferred Units during 2021 and 2020 (in millions, except for per unit amounts):

Three Months Ended

Record Date

Payment Date

Per Unit Distribution

Total Cash Distribution

March 31, 2021(1)

April 26, 2021

May 14, 2021

0.5873

December 31, 2020

February 12, 2021

0.625

September 30, 2020

November 3, 2020

November 13, 2020

0.625

June 30, 2020

August 4, 2020

August 14, 2020

0.625

March 31, 2020

May 5, 2020

May 15, 2020

0.625

_____________________

(1)The Board of Directors declared a $0.5873 per Series A Preferred Unit cash distribution on April 26, 2021, to be paid on May 14, 2021, to Series A Preferred unitholders of record at the close of business on April 26, 2021.

Impairment of Property, Plant and Equipment and Goodwill	3 Months Ended
	Mar. 31, 2021
Impairment of Property, Plant and Equipment and Goodwill [Abstract]
Impairment of Property, Plant and Equipment and Goodwill [Text Block]	(7) Impairments of Property, Plant and Equipment and Goodwill Impairment of Property, Plant and Equipment The Partnership periodically evaluates property, plant and equipment for impairment when events or changes in circumstances indicate that the carrying value of these assets may not be recoverable. The determination of whether an impairment has occurred is based on an estimate of undiscounted cash flows attributable to the assets, as compared to the carrying value of the assets. Due to decreases in natural gas and NGL market prices during 2020 as a result of the ongoing COVID-19 pandemic and the economic effects of the pandemic, together with the dispute over crude oil production levels between Russia and members of OPEC led by Saudi Arabia, as of March 31, 2020, management reassessed the carrying value of the Atoka assets, in which the Partnership owns a 50% interest in the consolidated joint venture, which is a component of the gathering and processing segment. Based on forecasted future undiscounted cash flows, management determined that the carrying value of the Atoka assets were not fully recoverable. The Partnership utilized the income approach (generally accepted valuation approach) to estimate the fair value of these assets. The primary inputs were forecasted cash flows and the discount rate. The fair value measurement is based on inputs that are not observable in the market and thus represent Level 3 inputs. Applying a discounted cash flow model to the property, plant and equipment, the Partnership recognized a $16 million impairment, which is included in Impairments of property, plant and equipment and goodwill on the Condensed Consolidated Statements of Income during the three months ended March 31, 2020. Impairment of Goodwill In the fourth quarter of 2017, as a result of the acquisition of ETGP, the Partnership recorded $12 million of goodwill associated with the Ark-La-Tex Basin reporting unit, included in the gathering and processing reportable segment. The Partnership tests its goodwill for impairment annually on October 1st, or more frequently if events or changes in circumstances indicate that the carrying value of goodwill may not be recoverable. Goodwill is assessed for impairment by comparing the fair value of the reporting unit with its book value, including goodwill. During 2020, the commodity price declines due to the existing oversupply of crude oil, NGLs and natural gas were exacerbated by the ongoing COVID-19 pandemic and the economic effects of the pandemic, in addition to the dispute over crude oil production levels between Russia and members of OPEC led by Saudi Arabia in the first quarter. Despite the subsequent agreement in April 2020 by a coalition of nations including Russia and Saudi Arabia to reduce production of crude oil, the price of NGLs and crude oil had remained significantly lower than pre-pandemic levels. Amid such crude oil, NGL and natural gas price declines, producers had been cutting back spending and shifting their focus from emphasizing reserves growth, to increasing net cash flows and reducing outstanding debt, which consequently resulted in a decrease in rig count and in forecasted producer activity in the Ark-La-Tex Basin reporting unit during the first quarter of 2020. At the same time, unit prices and market multiples for midstream companies with gathering and processing operations had dropped to their lowest levels in the last three years. Due to the continuing decrease in forward commodity prices, the reduction in forecasted producer activities, the resulting decrease in our forecasted cash flows and the increase in the weighted average cost of capital, the Partnership determined that the fair value of the goodwill associated with our Ark-La-Tex Basin reporting unit would more likely than not be impaired. As a result, the Partnership performed a quantitative test for our goodwill and determined that the carrying value of the Ark-La-Tex Basin reporting unit exceeded its fair value and that goodwill associated with the Ark-La-Tex Basin was completely impaired in the amount of $12 million. The impairment is included in Impairments of property, plant and equipment and goodwill on the Condensed Consolidated Statements of Income for the three months ended March 31, 2020. The Partnership had no goodwill recorded as of March 31, 2021 and December 31, 2020.

Investment in Equity Method Affiliate

3 Months Ended

Mar. 31, 2021

Equity Method Investments and Joint Ventures [Abstract]

Investment in Equity Method Affiliate

The Partnership uses the equity method of accounting for investments in entities in which it has an ownership interest between 20% and 50% and exercises significant influence.

SESH is owned 50% by Enbridge, Inc. and 50% by the Partnership. Pursuant to the terms of the SESH LLC Agreement, if, at any time, CenterPoint Energy has a right to receive less than 50% of our distributions through its interest in the Partnership and its economic interest in Enable GP, or does not have the ability to exercise certain control rights, Enbridge, Inc. may, under certain circumstances, have the right to purchase the Partnership’s interest in SESH at fair market value, subject to certain exceptions.

The Partnership shares operations of SESH with Enbridge, Inc. under service agreements. The Partnership is responsible for the field operations of SESH. SESH reimburses each party for actual costs incurred, which are billed based upon a combination of direct charges and allocations. The Partnership billed SESH $2 million and $6 million during the three months ended March 31, 2021 and 2020, respectively, associated with these service agreements.

The Partnership includes equity in earnings of equity method affiliate, net under the Other Income (Expense) caption in the Condensed Consolidated Statements of Income. The following table presents the amount of Equity in earnings of equity method affiliate recognized and Distributions from equity method affiliate received.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Equity in earnings of equity method affiliate		$	1	$	6


Distributions from equity method affiliate (1)		4		10

___________________

(1)Distributions from equity method affiliate includes a $1 million and $6 million return on investment and a $3 million and $4 million return of investment for the three months ended March 31, 2021 and 2020, respectively.

The following table includes the summarized financial information of SESH.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Income Statements:
Revenues		$	15	$	27
Operating income		4		16
Net income (loss)		(1)		11

Debt

3 Months Ended

Mar. 31, 2021

Debt Disclosure [Abstract]

Debt

The following table presents the Partnership’s outstanding debt.


	March 31, 2021						December 31, 2020
	Outstanding Principal		Discount (1)		Total Debt		Outstanding Principal		Discount (1)		Total Debt

	(In millions)
Commercial Paper	$	214	$	—	$	214	$	250	$	—	$	250

2019 Term Loan Agreement	800		—		800		800		—		800
2024 Notes	600		—		600		600		—		600
2027 Notes	700		(2)		698		700		(2)		698
2028 Notes	800		(4)		796		800		(5)		795
2029 Notes	547		(1)		546		547		(1)		546
2044 Notes	531		—		531		531		—		531
Total debt	$	4,192	$	(7)	$	4,185	$	4,228	$	(8)	$	4,220
Less: Short-term debt (2)					214						250
Less: Current portion of long-term debt (3)					800						—
Less: Unamortized debt expense (4)					19						19
Total long-term debt					$	3,152					$	3,951

____________________

(1)Unamortized discount on long-term debt is amortized over the life of the respective debt.

(2)Short-term debt includes $214 million and $250 million of outstanding commercial paper as of March 31, 2021 and December 31, 2020, respectively.

(3)As of March 31, 2021, Current portion of long-term debt included $800 million outstanding balance of the 2019 Term Loan Agreement.

(4)As of both March 31, 2021 and December 31, 2020, there was an additional $3 million of unamortized debt expense related to the Revolving Credit Facility included in Other assets, not included above.

Commercial Paper

The Partnership has a commercial paper program, pursuant to which the Partnership is authorized to issue up to $1.4 billion of commercial paper. The commercial paper program is supported by our Revolving Credit Facility, and outstanding commercial paper effectively reduces our borrowing capacity thereunder. There were $214 million and $250 million outstanding under our commercial paper program at March 31, 2021 and December 31, 2020, respectively. As of March 31, 2021, the weighted average interest rate for the outstanding commercial paper was 0.73%.

Revolving Credit Facility

The Partnership’s Revolving Credit Facility is a $1.75 billion, five-year senior unsecured revolving credit facility, which under certain circumstances may be increased from time to time up to an additional $875 million. The Revolving Credit Facility is scheduled to mature on April 6, 2023, subject to an extension option, which could be exercised two times to extend the term of the Revolving Credit Facility, in each case, for an additional one-year term. As of March 31, 2021, there were no principal advances, $3 million letters of credit outstanding and our available borrowing capacity was approximately $980 million under our Revolving Credit Facility.

The Revolving Credit Facility provides that outstanding borrowings bear interest at the LIBOR and/or an alternate base rate, at the Partnership’s election, plus an applicable margin. The applicable margin is based on the Partnership’s designated credit ratings from S&P, Moody’s and Fitch Ratings. As of March 31, 2021, the applicable margin for LIBOR-based borrowings under the Revolving Credit Facility was 1.50% based on the Partnership’s credit ratings. In addition, the Revolving Credit Facility requires the Partnership to pay a fee on unused commitments. The commitment fee is based on the Partnership’s credit ratings. As of March 31, 2021, the commitment fee under the restated Revolving Credit Facility was 0.20% per annum based on the Partnership’s credit ratings. The commitment fee is recorded as interest expense in the Partnership’s Condensed Consolidated Statements of Income.

2019 Term Loan Agreement

On January 29, 2019, the Partnership entered into an unsecured term loan agreement with Bank of America, N.A., as administrative agent, and the several lenders thereto. As of March 31, 2021, there was $800 million outstanding under the 2019 Term Loan Agreement. The 2019 Term Loan Agreement has a scheduled maturity date of January 29, 2022, but contains an option, which may be exercised up to two times, to extend the maturity date for an additional one-year term. The 2019 Term Loan Agreement provides that outstanding borrowings bear interest at the eurodollar rate and/or an alternate base rate, at the Partnership’s election, plus an applicable margin. The applicable margin is based on the Partnership’s credit ratings. The applicable margin shall equal, (1) in the case of interest rates determined by reference to the eurodollar rate, between 0.75% and 1.50% per annum and (2) in the case of interest rates determined by reference to the alternate base rate, between 0% and 0.50% per annum. As of March 31, 2021, the applicable margin for LIBOR-based advances under the 2019 Term Loan Facility was 1.25% based on the Partnership’s credit ratings. As of March 31, 2021, the weighted average interest rate of the 2019 Term Loan Agreement was 2.08%, including the impact of the associated interest rate derivatives designated as hedging instruments for accounting purposes.

Senior Notes

As of March 31, 2021, the Partnership’s debt included the 2024 Notes, 2027 Notes, 2028 Notes, 2029 Notes and 2044 Notes, which had $7 million of unamortized discount and $19 million of unamortized debt expense at March 31, 2021, resulting in effective interest rates of 4.01%, 4.56%, 5.19%, 4.30% and 5.08%, respectively, during the three months ended March 31, 2021. In March 2020, the Partnership’s EOIT Senior Notes matured and were paid using proceeds from the Revolving Credit Facility.

As of March 31, 2021, the Partnership was in compliance with all of its debt agreements, including financial covenants.

Derivative Instruments and Hedging Activities

3 Months Ended

Mar. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

The primary risks managed using derivative instruments are commodity price and interest rate risks.

Derivatives Not Designated as Hedging Instruments

Derivative instruments not designated as hedging instruments for accounting purposes are utilized to manage the Partnership’s exposure to commodity price risk. For derivative instruments not designated as hedging instruments, the gain or loss on the derivative is recognized currently in earnings.

Quantitative Disclosures Related to Derivative Instruments Not Designated as Hedging Instruments

The following table presents the Partnership’s derivative instruments that were not designated as hedging instruments for accounting purposes.


	March 31, 2021		December 31, 2020
	Gross Notional Volume
	Purchases	Sales	Purchases	Sales
Natural gas— TBtu (1)
Financial fixed futures/swaps	1	17	—	18
Financial basis futures/swaps	1	34	—	27
Financial swaptions (2)	—	5	—	7

Crude oil (for condensate)— MBbl (3)
Financial futures/swaps	—	420	—	465
Financial swaptions (2)	—	150	—	90
Natural gas liquids— MBbl (4)
Financial futures/swaps	435	1,155	855	1,210
Financial options	—	30	—	45

____________________

(1)As of March 31, 2021, 99.2% of the natural gas contracts had durations of one year or less and 0.8% had durations of more than one year and less than two years. As of December 31, 2020, 95.7% of the natural gas contracts had durations of one year or less and 4.3% had durations of more than one year and less than two years.

(2)The notional volume contains a combined derivative instrument consisting of a fixed price swap and a sold option, which gives the counterparties the right, but not the obligation, to increase the notional volume hedged under the fixed price swap until the option expiration date. The notional volume represents the volume prior to option exercise.

(3)As of March 31, 2021, 89.5% of the crude oil (for condensate) contracts had durations of one year or less and 10.5% had durations of more than one year and less than two years. As of December 31, 2020, 100.0% of the crude oil (for condensate) contracts had durations of one year or less.

(4)As of March 31, 2021, 97.2% of the natural gas liquids contracts had durations of one year or less and 2.8% had durations of more than one year and less than two years. As of December 31, 2020, 100.0% of the natural gas liquids contracts had durations of one year or less.

Derivatives Designated as Hedging Instruments

Derivative instruments designated as hedging instruments for accounting purposes are utilized in managing the Partnership’s interest rate risk exposures.

Quantitative Disclosures Related to Derivative Instruments Designated as Hedging Instruments

The following table presents the Partnership’s derivative instruments that were designated as hedging instruments for accounting purposes.


	March 31, 2021		December 31, 2020
	Gross Notional Value
	(In millions)
Interest rate swaps	$	300	$	300

Balance Sheet Presentation Related to Derivative Instruments

The following table presents the fair value of the derivative instruments that are included in the Partnership’s Condensed Consolidated Balance Sheets that were not designated as hedging instruments for accounting purposes.


		March 31, 2021				December 31, 2020
		Fair Value
Instrument	Balance Sheet Location	Assets		Liabilities		Assets		Liabilities

		(In millions)
Natural gas
Financial futures/swaps	Other Current	$	1	$	3	$	2	$	2
Financial swaptions	Other Current	1		2		1		2




Crude oil (for condensate)
Financial futures/swaps	Other Current	—		10		1		13
Financial swaptions	Other Current	—		1		—		—


Natural gas liquids
Financial futures/swaps	Other Current	9		6		15		3
Financial swaptions	Other Current	—		1		—		1

Total gross commodity derivatives (1)		$	11	$	23	$	19	$	21

_____________________

(1)See Note 11 for a reconciliation of the Partnership’s commodity derivatives fair value to the Partnership’s Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020.

The following table presents the fair value of the derivative instruments that are included in the Partnership’s Condensed Consolidated Balance Sheets that were designated as hedging instruments for accounting purposes.


		March 31, 2021				December 31, 2020
		Fair Value
Instrument	Balance Sheet Location	Assets		Liabilities		Assets		Liabilities

		(In millions)
Interest rate swaps (1)	Other Current	$	—	$	5	$	—	$	6

_____________________

(1)All interest rate derivative instruments that were designated as cash flow hedges are considered Level 2 as of March 31, 2021 and December 31, 2020.

Income Statement Presentation Related to Derivative Instruments

The following table presents the effect of derivative instruments on the Partnership’s Condensed Consolidated Statements of Income.


		Amounts Recognized in Income
	Three Months Ended March 31,
		2021		2020

		(In millions)
Natural gas
Financial futures/swaps gains (losses)		$	(2)	$	4
Financial swaptions losses		—		(1)
Physical purchases/sales gains		—		1
Crude oil (for condensate)
Financial futures/swaps gains (losses)		(6)		19
Financial swaptions gains (losses)		(1)		4
Natural gas liquids
Financial futures/swaps losses		(5)		(7)
Total		$	(14)	$	20

For derivatives not designated as hedges in the tables above, amounts recognized in income for the periods ended March 31, 2021 and 2020, if any, are reported in Product sales.

The following table presents the components of gain (loss) on derivative activity in the Partnership’s Condensed Consolidated Statements of Income.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Change in fair value of commodity derivatives		$	(10)	$	10
Realized gain (loss) on commodity derivatives		(4)		10
Gain (loss) on commodity derivative activity		$	(14)	$	20

The following table presents the effect of derivative instruments that were designated as hedging instruments on the Partnership’s Condensed Consolidated Statements of Income.


		Amounts Recognized in Income
	Three Months Ended March 31,
		2021		2020

		(In millions)
Interest rate swaps losses		$	(1)	$	—

Interest rate derivatives designated as hedges are recognized in income once settled. Settlement amounts recognized in income for the periods ended March 31, 2021 and 2020 are reported in Interest expense.

Credit-Risk Related Contingent Features in Derivative Instruments

In the event Moody’s or S&P were to lower the Partnership’s senior unsecured debt rating to a below investment grade rating, the Partnership could be required to provide additional credit assurances to third parties, which could include letters of credit or cash collateral to satisfy its obligation under its financial and physical contracts relating to derivative instruments that are in a net liability position. As of March 31, 2021, under these obligations, the Partnership had posted no cash collateral related to natural gas swaps and swaptions, crude oil swaps and swaptions and NGL swaps and $1 million of additional collateral would be required to be posted by the Partnership in the event of a credit ratings downgrade to a below investment grade rating. In certain situations where the Partnership’s credit rating is lowered by Moody’s or S&P, the Partnership could be subject to an early termination event related to certain derivative instruments, which could result in a cash settlement of the instruments at market values on the date of such early termination.

Fair Value Measurements

3 Months Ended

Mar. 31, 2021

Fair Value Disclosures [Abstract]

Fair Value Measurements

Certain assets and liabilities are recorded at fair value in the Condensed Consolidated Balance Sheets and are categorized based upon the level of judgment associated with the inputs used to measure their value. The Partnership determines the appropriate level for each financial asset and liability on a quarterly basis and recognizes transfers between levels at the end of the reporting period. For the three months ended March 31, 2021, there were no transfers between levels. As of March 31, 2021, there were no contracts classified as Level 3.

Estimated Fair Value of Financial Instruments

The fair values of all accounts receivable, notes receivable, accounts payable, commercial paper and other such financial instruments on the Condensed Consolidated Balance Sheets are estimated to be approximately equivalent to their carrying amounts due to their short-term nature and have been excluded from the table below.

The following table summarizes the fair value and carrying amount of the Partnership’s financial instruments.


	March 31, 2021				December 31, 2020
	Carrying Amount		Fair Value		Carrying Amount		Fair Value

	(In millions)
Debt
Revolving Credit Facility (Level 2) (1)	$	—	$	—	$	—	$	—
2019 Term Loan Agreement (Level 2)	800		800		800		800
2024 Notes (Level 2)	600		639		600		612
2027 Notes (Level 2)	698		758		698		709
2028 Notes (Level 2)	796		884		795		817
2029 Notes (Level 2)	546		568		546		544
2044 Notes (Level 2)	531		527		531		499

____________________

(1) Borrowing capacity is effectively reduced by our borrowings outstanding under the commercial paper program. $214 million and $250 million of commercial paper was outstanding as of March 31, 2021 and December 31, 2020, respectively.

The fair value of the Partnership’s Revolving Credit Facility, 2019 Term Loan Agreement, 2024 Notes, 2027 Notes, 2028 Notes, 2029 Notes, and 2044 Notes is based on quoted market prices and estimates of current rates available for similar issues with similar maturities and is classified as Level 2 in the fair value hierarchy.

Non-Financial Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

Certain assets and liabilities are measured at fair value on a nonrecurring basis; that is, the assets and liabilities are not measured at fair value on an ongoing basis but are subject to fair value adjustments in certain circumstances (e.g., when there is evidence of impairment). As of March 31, 2021, no material fair value adjustments or fair value measurements were required for these non-financial assets or liabilities.

Based upon review of forecast undiscounted cash flows as of March 31, 2021, all of the asset groups were considered recoverable. Based upon review for other than temporary declines in fair value, the investment in equity method affiliate was considered recoverable. Future price declines, throughput declines, contracted capacity declines, cost increases, regulatory or political environment changes and other changes in market conditions, including the oversupply of crude oil, NGLs and natural gas as well as the ongoing COVID-19 pandemic and the economic effects of the pandemic, could reduce forecast undiscounted cash flows for the asset groups and result in other than temporary declines in the fair value of the investment in equity method affiliate.

Contracts with Master Netting Arrangements

As of March 31, 2021, the Partnership’s Level 2 interest rate derivatives are recorded as liabilities with no netting adjustments.

The following tables summarize the Partnership’s other assets and liabilities that are measured at fair value on a recurring basis.


March 31, 2021	Commodity Contracts				Gas Imbalances (1)
	Assets		Liabilities		Assets (2)		Liabilities (3)

	(In millions)
Quoted market prices in active market for identical assets (Level 1)	$	1	$	10	$	—	$	—
Significant other observable inputs (Level 2)	10		13		30		10

Total fair value	11		23		30		10
Netting adjustments	(11)		(11)		—		—
Total	$	—	$	12	$	30	$	10


December 31, 2020	Commodity Contracts				Gas Imbalances (1)
	Assets		Liabilities		Assets (2)		Liabilities (3)

	(In millions)
Quoted market prices in active market for identical assets (Level 1)	$	2	$	14	$	—	$	—
Significant other observable inputs (Level 2)	17		7		23		16

Total fair value	19		21		23		16
Netting adjustments	(19)		(19)		—		—
Total	$	—	$	2	$	23	$	16

______________________

(1)The Partnership uses the market approach to fair value its gas imbalance assets and liabilities at individual, or where appropriate an average of, current market indices applicable to the Partnership’s operations, not to exceed net realizable value. There were no netting adjustments as of March 31, 2021 and December 31, 2020.

(2)Gas imbalance assets exclude fuel reserves for under retained fuel due from shippers of $19 million and $19 million at March 31, 2021 and December 31, 2020, respectively, which fuel reserves are based on the value of natural gas at the time the imbalance was created, and which are not subject to revaluation at fair market value.

(3)Gas imbalance liabilities exclude fuel reserves for over retained fuel due to shippers of $3 million and $3 million at March 31, 2021 and December 31, 2020, respectively, which fuel reserves are based on the value of natural gas at the time the imbalance was created, and which are not subject to revaluation at fair market value.

- Definition

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References + Details

Supplemental Disclosure of Cash Flow Information

3 Months Ended

Mar. 31, 2021

Supplemental Cash Flow Information [Abstract]

Supplemental Disclosure of Cash Flow Information

The following table provides information regarding supplemental cash flow information:


	Three Months Ended March 31,
	2021		2020

	(In millions)
Supplemental Disclosure of Cash Flow Information:
Cash Payments:
Interest, net of capitalized interest	$	32	$	43
Income taxes, net of refunds	(2)		—
Non-cash transactions:
Accounts payable related to capital expenditures	7		8
Lease liabilities related to derecognition of right-of-use assets	—		(4)
Impact of adoption of financial instruments-credit losses accounting standard (Note 1)	—		(3)

Related Party Transactions

3 Months Ended

Mar. 31, 2021

Related Party Transactions

The Partnership’s revenues from affiliated companies accounted for 7% and 8% of total revenues during the three months ended March 31, 2021 and 2020, respectively. The following table presents the amounts of revenues from affiliated companies included in the Partnership’s Condensed Consolidated Statements of Income.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Gas transportation and storage service revenues — CenterPoint Energy		$	27	$	37

Gas transportation and storage service revenues — OGE Energy		10		9
Natural gas product sales — OGE Energy		31		5
Total revenues — affiliated companies		$	68	$	51

The following table presents the amounts of natural gas purchased from affiliated companies included in the Partnership’s Condensed Consolidated Statements of Income.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Cost of natural gas purchases — CenterPoint Energy		$	—	$	1
Cost of natural gas purchases — OGE Energy		31		8
Total cost of natural gas purchases — affiliated companies		$	31	$	9

Corporate services and seconded employees

The Partnership receives services and support functions from each of CenterPoint Energy and OGE Energy under services agreements for an initial term that ended on April 30, 2016. The services agreements automatically extend year-to-year at the end of the initial term, unless terminated by the Partnership with at least 90 days’ notice prior to the end of any extension. Additionally, the Partnership may terminate the services agreements at any time with 180 days’ notice, if approved by the Board of Enable GP. The Partnership reimburses CenterPoint Energy and OGE Energy for these services up to annual caps, which for 2021 are both less than $1 million.

As of March 31, 2021, the Partnership had certain employees who are participants under OGE Energy’s defined benefit and retiree medical plans, who will remain seconded to the Partnership, subject to certain termination rights of the Partnership and OGE Energy. The Partnership’s reimbursement of OGE Energy for seconded employee costs arising out of OGE Energy’s defined benefit and retiree medical plans is fixed at actual cost subject to an annual cap of $5 million until secondment is terminated.

The following table presents the amounts charged to the Partnership by affiliates for seconded employees, included primarily in Operation and maintenance and General and administrative expenses in the Partnership’s Condensed Consolidated Statements of Income.


	Three Months Ended March 31,
		2021		2020

		(In millions)


Seconded Employee Costs — OGE Energy		$	4	$	3

Commitments and Contingencies	3 Months Ended
Commitments and Contingencies	Mar. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies The Partnership is involved in legal, environmental, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies regarding matters arising in the ordinary course of business. Some of these proceedings involve substantial amounts. The Partnership regularly analyzes current information and, as necessary, provides accruals for probable liabilities on the eventual disposition of these matters. The Partnership does not expect the disposition of these matters to have a material adverse effect on its financial condition, results of operations or cash flows. On January 1, 2017, the Partnership entered into a 10-year gathering and processing agreement, which became effective on July 1, 2018, with an affiliate of Energy Transfer for deliveries to the Godley Plant in Johnson County, Texas. As of March 31, 2021, the Partnership estimates the remaining associated minimum volume commitment fee to be $164 million. Minimum volume commitment fees are expected to be $15 million for the remainder of 2021, $23 million per year from 2022 through 2027 and $11 million in 2028. On September 13, 2018, the Partnership executed a precedent agreement for the development of the Gulf Run Pipeline, an interstate natural gas transportation project. On January 30, 2019, a final investment decision was made by Golden Pass LNG, the cornerstone shipper for the liquefied natural gas facility to be served by the Gulf Run Pipeline project. Subject to approval of the project by FERC, the Partnership will be required to construct a large-diameter pipeline from northern Louisiana to Gulf Coast markets. In addition, the Partnership requested approval to transfer existing EGT transportation infrastructure to the Gulf Run Pipeline. The Partnership filed applications with FERC to obtain authorization to construct and operate the pipeline on February 28, 2020. FERC issued the environmental assessment on October 29, 2020. The Partnership estimates the cost to complete the Gulf Run Pipeline project would be as much as $540 million. The project is backed by a 20-year firm transportation service agreement. The Gulf Run Pipeline connects natural gas producing regions in the U.S., including the Haynesville, Marcellus, Utica and Barnett shales and the Mid-Continent region. The project is expected to be placed into service in late 2022.

Equity-Based Compensation

3 Months Ended

Mar. 31, 2021

Share-based Payment Arrangement [Abstract]

Equity-Based Compensation

The following table summarizes the Partnership’s equity-based compensation expense related to performance units and phantom units for the Partnership’s employees and independent directors.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Performance units		$	2	$	2

Phantom units		2		2
Total compensation expense		$	4	$	4

The following table presents the assumptions related to the performance units granted in 2021.


	2021
Number of units granted	1,453,897
Fair value of units granted	$	10.26
Expected distribution yield	12.90		%
Expected price volatility	100.00		%
Risk-free interest rate	0.27		%
Expected life of units (in years)	3

The following table presents the number of phantom units granted and the grant date fair value related to the phantom units granted in 2021.


			2021
Phantom Units granted			1,356,672
Fair value of phantom units granted			$5.41 - $6.87

Units Outstanding

A summary of the activity for the Partnership’s performance units and phantom units applicable to the Partnership’s employees at March 31, 2021 and changes during 2021 are shown in the following table.


	Performance Units				Phantom Units
	Number of Units		Weighted Average Grant-Date Fair Value, Per Unit			Number of Units		Weighted Average Grant-Date Fair Value, Per Unit

	(In millions, except unit data)
Units outstanding at December 31, 2020	1,765,508		$	13.10		1,790,845		$	10.29
Granted (1)	1,453,897		10.26			1,356,672		6.86

Vested (2)	(389,817)		17.70			(461,824)		13.11
Forfeited	(32,625)		10.00			(94,669)		8.70
Units outstanding at March 31, 2021	2,796,963		$	11.02		2,591,024		$	8.05
Aggregate intrinsic value of units outstanding at March 31, 2021	$	18				$	17

_____________________

(1)Performance units represents the target number of performance units granted. The actual number of performance units earned, if any, is dependent upon performance and may range from 0% to 200% of the target.

(2)Performance units vested as of March 31, 2021 include 389,817 units from the 2018 annual grant, which were approved by the Board of Directors in 2018 and, based on the level of achievement of a performance goal established by the Board of Directors over the performance period of January 1, 2018 through December 31, 2020, no performance units vested.

Unrecognized Compensation Cost

The following table summarizes the Partnership’s unrecognized compensation cost for its non-vested performance units and phantom units, and the weighted-average periods over which the compensation cost is expected to be recognized.


	March 31, 2021
	Unrecognized Compensation Cost (In millions)		Weighted Average Period for Recognition (In years)
Performance Units	$	21	2.25

Phantom Units	14		2.07
Total	$	35

As of March 31, 2021, there were 3,105,706 units available for issuance under the long-term incentive plan.

Reportable Segments

3 Months Ended

Mar. 31, 2021

Segment Reporting [Abstract]

Reportable Segments

The Partnership’s determination of reportable segments considers the strategic operating units under which it manages sales, allocates resources and assesses performance of various products and services to customers in differing regulatory environments. The accounting policies of the reportable segments are the same as those described in the summary of significant accounting policies excerpt in the Partnership’s audited 2020 Notes to Consolidated Financial Statements included in the Annual Report. The Partnership uses operating income as the measure of profit or loss for its reportable segments.

The Partnership’s assets and operations are organized into two reportable segments: (i) gathering and processing and (ii) transportation and storage. Our gathering and processing segment primarily provides natural gas gathering and processing services to our producer customers and crude oil, condensate and produced water gathering services to our producer and refiner customers. The transportation and storage segment provides interstate and intrastate natural gas pipeline transportation and storage services primarily to our producer, power plant, LDC and industrial end-user customers.

Financial data for reportable segments are as follows:


Three Months Ended March 31, 2021	Gathering and Processing		Transportation (1) and Storage		Eliminations		Total

	(In millions)
Product sales	$	428	$	332	$	(133)	$	627
Service revenues	196		150		(3)		343
Total Revenues	624		482		(136)		970
Cost of natural gas and natural gas liquids (excluding depreciation and amortization shown separately)	398		257		(136)		519
Operation and maintenance, General and administrative	79		42		—		121
Depreciation and amortization	74		32		—		106

Taxes other than income tax	11		7		—		18
Operating income	$	62	$	144	$	—	$	206
Total Assets	$	10,780	$	5,789	$	(4,805)	$	11,764
Capital expenditures	$	21	$	59	$	—	$	80


Three Months Ended March 31, 2020	Gathering and Processing		Transportation (1) and Storage		Eliminations		Total

	(In millions)
Product sales	$	275	$	75	$	(62)	$	288
Service revenues	202		159		(1)		360
Total Revenues	477		234		(63)		648
Cost of natural gas and natural gas liquids (excluding depreciation and amortization shown separately)	211		78		(63)		226
Operation and maintenance, General and administrative	81		45		—		126
Depreciation and amortization	74		30		—		104
Impairments of property, plant and equipment and goodwill	28		—		—		28
Taxes other than income tax	11		7		—		18
Operating income	$	72	$	74	$	—	$	146
Total assets as of December 31, 2020	$	10,830	$	5,729	$	(4,830)	$	11,729
Capital expenditures	$	34	$	20	$	—	$	54

_____________________

(1)See Note 8 for discussion regarding ownership interests in SESH and related equity earnings included in the transportation and storage segment for the three months ended March 31, 2021 and 2020.

^[1]

[1]	See Note 8 for discussion regarding ownership interests in SESH and related equity earnings included in the transportation and storage segment for the three months ended March 31, 2021 and 2020.

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
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-Section 50
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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Reference 5: http://www.xbrl.org/2003/role/disclosureRef
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Reference 6: http://www.xbrl.org/2003/role/disclosureRef
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Reference 7: http://www.xbrl.org/2003/role/disclosureRef
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-Topic 280
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Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 14: http://www.xbrl.org/2003/role/disclosureRef
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+ Details

Summary of Significant Accounting Policies (Policies)	3 Months Ended
Summary of Significant Accounting Policies (Policies)	Mar. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization	Organization Enable Midstream Partners, LP (the Partnership) is a Delaware limited partnership whose assets and operations are organized into two reportable segments: (i) gathering and processing and (ii) transportation and storage. Our gathering and processing segment primarily provides natural gas gathering and processing services to our producer customers and crude oil, condensate and produced water gathering services to our producer and refiner customers. The transportation and storage segment provides interstate and intrastate natural gas pipeline transportation and storage services primarily to our producer, power plant, LDC and industrial end-user customers. Our natural gas gathering and processing assets are primarily located in Oklahoma, Texas, Arkansas and Louisiana and serve natural gas production in the Anadarko, Arkoma and Ark-La-Tex Basins. Crude oil gathering assets are located in Oklahoma and serve crude oil production in the SCOOP and STACK plays of the Anadarko Basin and in North Dakota and serve crude oil production in the Bakken Shale formation of the Williston Basin. The Partnership’s natural gas transportation and storage assets consist primarily of an interstate pipeline system extending from western Oklahoma and the Texas Panhandle to Louisiana, an interstate pipeline system extending from Louisiana to Illinois, an intrastate pipeline system in Oklahoma, and our investment in SESH, a pipeline extending from Louisiana to Alabama. CenterPoint Energy and OGE Energy each have 50% of the management interests in Enable GP. Enable GP is the general partner of the Partnership and has no other operating activities. Enable GP is governed by a board made up of two representatives designated by each of CenterPoint Energy and OGE Energy, along with the Partnership’s Chief Executive Officer and three independent board members CenterPoint Energy and OGE Energy mutually agreed to appoint. CenterPoint Energy and OGE Energy also own a 40% and 60% interest, respectively, in the incentive distribution rights held by Enable GP. As of March 31, 2021, CenterPoint Energy held approximately 53.7% or 233,856,623 of the Partnership’s common units, and OGE Energy held approximately 25.5% or 110,982,805 of the Partnership’s common units. Additionally, CenterPoint Energy holds 14,520,000 Series A Preferred Units. The limited partner interests of the Partnership have limited voting rights on matters affecting the business. As such, limited partners do not have rights to elect the Partnership’s general partner on an annual or continuing basis and may not remove Enable GP, its current general partner, without at least a 75% vote by all unitholders, including all units held by the Partnership’s limited partners, and Enable GP and its affiliates, voting together as a single class. As of March 31, 2021, the Partnership owned a 50% interest in SESH. See Note 8 for further discussion of SESH. For the three months ended March 31, 2021, the Partnership owned a 50% ownership in Atoka and consolidated Atoka in the accompanying Condensed Consolidated Financial Statements as EOIT acted as the managing member of Atoka and had control over the operations of Atoka. In addition, the Partnership held a 60% interest in ESCP, which is consolidated in the accompanying Condensed Consolidated Financial Statements as EOCS acted as the managing member of ESCP and had control over the operations of ESCP.
Basis of Presentation	Basis of Presentation The accompanying Condensed Consolidated Financial Statements and related notes of the Partnership have been prepared pursuant to the rules and regulations of the SEC and GAAP. Pursuant to such rules and regulations, certain disclosures normally included in financial statements prepared in accordance with GAAP have been omitted. The accompanying Condensed Consolidated Financial Statements and related notes should be read in conjunction with the Consolidated Financial Statements and related notes included in our Annual Report. The Condensed Consolidated Financial Statements and the related notes reflect all normal recurring adjustments that are, in the opinion of management, necessary to present fairly the financial position and results of operations for the respective periods. Amounts reported in the Partnership’s Condensed Consolidated Statements of Income are not necessarily indicative of amounts expected for a full-year period due to the effects of, among other things, (a) seasonal fluctuations in demand for energy and energy services, (b) changes in energy commodity prices, (c) timing of maintenance and other expenditures, (d) acquisitions and dispositions of businesses, assets and other interests, and (e) the impact of the ongoing COVID-19 pandemic and the economic effects of the pandemic which have resulted in a substantial decrease in natural gas, NGLs and crude oil prices.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Depreciation Expense	Depreciation ExpenseOn March 26, 2020, FERC issued an order approving MRT’s 2018 Rate Case and 2019 Rate Case settlements. As a result of the settlements, the new depreciation rates for MRT have been applied in accordance with the order. The new depreciation rates did not result in a material change in depreciation expense or results of operations.
Accounts Receivable and Allowance for Doubtful Accounts	Accounts Receivable and Allowance for Doubtful Accounts The Partnership adopted ASU No. 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments” on January 1, 2020. Upon adoption, the Partnership recognized a $3 million cumulative adjustment to Partners’ Equity and a corresponding adjustment to Allowance for doubtful accounts. Accounts receivable are recorded at the invoiced amount and do not typically bear interest. The determination of the allowance for doubtful accounts requires management to make estimates and judgments regarding our customers’ ability to pay. The allowance for doubtful accounts is determined based primarily upon the historical loss-rate method established for various pools of accounts receivables with similar levels of credit risk. The historical loss-rates are then adjusted, as necessary, based on current conditions and forecast information that could result in future uncollectable amounts. On an ongoing basis, we evaluate our customers’ financial strength and liquidity based on aging of accounts receivable, payment history, and review of other relevant information, including ratings agency credit ratings and alerts, publicly available reports and news releases, and bank and trade references. It is the policy of management to review the outstanding accounts receivable and other receivable balances within other assets at least quarterly, giving consideration to credit losses, the aging of receivables, specific customer circumstances that may impact their ability to pay the amounts due and current and forecast economic conditions over the assets contractual lives.
Inventory	InventoryNatural gas inventory is held, through the transportation and storage segment, to provide operational support for pipeline deliveries and to manage leased intrastate storage capacity. Natural gas liquids inventory is held, through the gathering and processing segment, due to timing differences between the production of certain natural gas liquids and ultimate sale to third parties. Natural gas and natural gas liquids inventory is valued using moving average cost and is subsequently recorded at the lower of cost or net realizable value.
Impairment of Long-lived Assets (including Intangible Assets) and Impairment of Goodwill	Impairment of Long-Lived Assets (including Intangible Assets) The Partnership periodically evaluates long-lived assets, including property, plant and equipment, and specifically identifiable intangibles other than goodwill, when events or changes in circumstances indicate that the carrying value of these assets may not be recoverable. The determination of whether an impairment has occurred is based on an estimate of undiscounted cash flows attributable to the assets, as compared to the carrying value of the assets. For more information, see Note 7. Impairment of Goodwill The Partnership assesses its goodwill for impairment annually on October 1st, or more frequently if events or changes in circumstances indicate that the carrying value of goodwill may not be recoverable. Goodwill is assessed for impairment by comparing the fair value of the reporting unit with its book value, including goodwill. The Partnership utilizes the market or income approaches to estimate the fair value of the reporting unit, also giving consideration to the alternative cost approach. Under the market approach, historical and current year forecasted cash flows are multiplied by a market multiple to determine fair value. Under the income approach, anticipated cash flows over a period of years plus a terminal value are discounted to present value using appropriate discount rates. The resulting fair value of the reporting unit is then compared to the carrying amount of the reporting unit and an impairment charge is recorded to goodwill for the difference. The Partnership performs its goodwill impairment testing at the reporting unit, which is one level below the transportation and storage and gathering and processing reportable segment level. For more information, see Note 7.
New Accounting Pronouncements	Reference Rate Reform In March 2020, the FASB issued ASU No. 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting.” This standard provides optional guidance, for a limited time, to ease the potential burden in accounting for or recognizing the effects of reference rate reform on financial reporting. The standard was effective upon issuance and generally can be applied through December 31, 2022. The Partnership adopted ASU 2020-04 during the year ended December 31, 2020. The implementation had no material impact on the Consolidated Financial Statements and related disclosures. In January 2021, the FASB issued ASU No. 2021-01, “Reference Rate Reform (Topic 848): Scope.” This standard clarifies that certain optional expedients and exceptions in ASC 848 for contract modifications and hedge accounting apply to derivatives that are affected by the discounting transition. ASU 2021-01 also amends the expedients and exceptions in ASC 848 to capture the incremental consequences of the scope clarification and to tailor the existing guidance to derivative instruments affected by the discounting transition. ASU 2021-01 was effective upon issuance and generally can be applied through December 31, 2022. The Partnership adopted ASU 2021-01 during three months ended March 31, 2021. The implementation had no material impact on the Condensed Consolidated Financial Statements and related disclosures.
Derivatives Instruments and Hedging Activities	The primary risks managed using derivative instruments are commodity price and interest rate risks. Derivatives Not Designated as Hedging Instruments Derivative instruments not designated as hedging instruments for accounting purposes are utilized to manage the Partnership’s exposure to commodity price risk. For derivative instruments not designated as hedging instruments, the gain or loss on the derivative is recognized currently in earnings. Derivatives Designated as Hedging Instruments Derivative instruments designated as hedging instruments for accounting purposes are utilized in managing the Partnership’s interest rate risk exposures.
Fair Value Measurements	Certain assets and liabilities are recorded at fair value in the Condensed Consolidated Balance Sheets and are categorized based upon the level of judgment associated with the inputs used to measure their value. The Partnership determines the appropriate level for each financial asset and liability on a quarterly basis and recognizes transfers between levels at the end of the reporting period. For the three months ended March 31, 2021, there were no transfers between levels. As of March 31, 2021, there were no contracts classified as Level 3.
Reportable Segments	The Partnership’s determination of reportable segments considers the strategic operating units under which it manages sales, allocates resources and assesses performance of various products and services to customers in differing regulatory environments. The accounting policies of the reportable segments are the same as those described in the summary of significant accounting policies excerpt in the Partnership’s audited 2020 Notes to Consolidated Financial Statements included in the Annual Report. The Partnership uses operating income as the measure of profit or loss for its reportable segments. The Partnership’s assets and operations are organized into two reportable segments: (i) gathering and processing and (ii) transportation and storage. Our gathering and processing segment primarily provides natural gas gathering and processing services to our producer customers and crude oil, condensate and produced water gathering services to our producer and refiner customers. The transportation and storage segment provides interstate and intrastate natural gas pipeline transportation and storage services primarily to our producer, power plant, LDC and industrial end-user customers.

Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2021

Accounting Policies [Abstract]

Accounts Receivable, Allowance for Credit Loss

The following table summarizes the required allowance for doubtful accounts.


	March 31, 2021		December 31, 2020

	(In millions)
Accounts receivable	$	4	$	1
Other assets	3		3
Total Allowance for doubtful accounts	$	7	$	4

Revenue (Tables)

3 Months Ended

Mar. 31, 2021

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

The following tables disaggregate total revenues by major source from contracts with customers and the gain (loss) on derivative activity for the three months ended March 31, 2021 and 2020.


	Three Months Ended March 31, 2021
	Gathering and Processing		Transportation and Storage		Eliminations		Total

	(In millions)
Revenues:
Product sales:
Natural gas	$	112	$	330	$	(130)	$	312
Natural gas liquids	297		3		(3)		297
Condensate	32		—		—		32
Total revenues from natural gas, natural gas liquids, and condensate	441		333		(133)		641
Loss on derivative activity	(13)		(1)		—		(14)
Total Product sales	$	428	$	332	$	(133)	$	627
Service revenues:
Demand revenues	$	26	$	127	$	—	$	153
Volume-dependent revenues	170		23		(3)		190
Total Service revenues	$	196	$	150	$	(3)	$	343
Total Revenues	$	624	$	482	$	(136)	$	970


	Three Months Ended March 31, 2020
	Gathering and Processing		Transportation and Storage		Eliminations		Total

	(In millions)
Revenues:
Product sales:
Natural gas	$	56	$	73	$	(60)	$	69
Natural gas liquids	172		2		(2)		172
Condensate	27		—		—		27
Total revenues from natural gas, natural gas liquids, and condensate	255		75		(62)		268
Gain on derivative activity	20		—		—		20
Total Product sales	$	275	$	75	$	(62)	$	288
Service revenues:
Demand revenues	$	39	$	142	$	—	$	181
Volume-dependent revenues	163		17		(1)		179
Total Service revenues	$	202	$	159	$	(1)	$	360
Total Revenues	$	477	$	234	$	(63)	$	648

Schedule of Accounts Receivable

The following table summarizes the components of accounts receivable, net of allowance for doubtful accounts.


	March 31, 2021		December 31, 2020

	(In millions)
Accounts Receivable:
Customers	$	272	$	245
Contract assets (1)	21		12
Non-customers	4		6
Total Accounts Receivable (2)	$	297	$	263

____________________

(2)Total Accounts Receivable includes Accounts receivable, net of allowance for doubtful accounts and Accounts receivable—affiliated companies.

^[1],[2]

Summary of Timing Recognition of Contract Liabilities

The table below summarizes the change in the contract liabilities.


	March 31, 2021		December 31, 2020

	(In millions)
Deferred revenues, beginning of period (1)	$	44	$	48
Amounts recognized in revenues related to the beginning balance	(17)		(25)
Net additions	16		21
Deferred revenues, end of period (1)	$	43	$	44

____________________

(1)Deferred revenues includes deferred revenue—affiliated companies. This amount is included in Other current liabilities and Other long-term liabilities.

The table below summarizes the timing of recognition of these contract liabilities as of March 31, 2021.


	2021		2022		2023		2024		2025 and After
	(In millions)
Deferred revenues (1)	$	20	$	7	$	7	$	7	$	2

____________________

(1)Deferred revenues includes deferred revenue—affiliated companies. This amount is included in Other current liabilities and Other long-term liabilities.

^[3]

Summary of Timing Recognition of Remaining Performance Obligations

The table below summarizes the timing of recognition of the remaining performance obligations as of March 31, 2021.


	2021		2022		2023		2024		2025 and After
	(In millions)
Transportation and Storage	$	325	$	393	$	353	$	266	$	959
Gathering and Processing	93		123		121		101		213
Total remaining performance obligations	$	418	$	516	$	474	$	367	$	1,172

[1]	Contract assets reflected in Total Accounts Receivable include accrued minimum volume commitments. Contract assets are primarily attributable to revenues associated with estimated shortfall volumes on certain annual minimum volume commitment arrangements. Total Accounts Receivable does not include contract assets related to firm service transportation contracts with tiered rates of $10 million as of March 31, 2021 and $9 million as of December 31, 2020, which are reflected in Other Assets.
[2]	Total Accounts Receivable includes Accounts receivable, net of allowance for doubtful accounts and Accounts receivable—affiliated companies.
[3]	Deferred revenues includes deferred revenue—affiliated companies. This amount is included in Other current liabilities and Other long-term liabilities.

Leases (Tables)

3 Months Ended

Mar. 31, 2021

Leases [Abstract]

Schedule of Leasing Assets and Liabilities [Table Text Block]

The table below summarizes the operating leases included in the Condensed Consolidated Balance Sheets.


	Balance Sheet Location	March 31, 2021		December 31, 2020

		(In millions)
Operating lease asset	Other Assets	$	24	$	25
Total right-of-use assets		$	24	$	25

Operating lease liabilities	Other Current Liabilities	$	4	$	4
Operating lease liabilities	Other Liabilities	23		24
Total lease liabilities		$	27	$	28

Summary of Lease Expense

The following table presents the Partnership’s rental costs associated with field equipment and buildings.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Rental Costs:
Field equipment		$	3	$	5
Office space		1		1

The following table presents the Partnership’s lease cost.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Lease Cost:
Operating lease cost		$	1	$	2
Short-term lease cost		2		3
Variable lease cost		1		1
Total Lease Cost		$	4	$	6

Schedule of Operating Lease Obligations Expiration

Undiscounted cash flows for operating lease liabilities are as follows:


	Non-cancellable operating leases

	(In millions)
Year Ending December 31,
2021 - remainder	$	4
2022	5
2023	6
2024	4
2025	3
2026	2
After 2026	6
Total	30
Less: impact of the applicable discount rate	3
Total lease liabilities	$	27

Earnings Per Limited Partner Unit (Tables)

3 Months Ended

Mar. 31, 2021

Earnings Per Share [Abstract]

Schedule Of Earnings Per Unit For Common Units

The following table illustrates the Partnership’s calculation of earnings per unit for common units.


	Three Months Ended March 31,
		2021		2020

		(In millions, except per unit data)
Net income		$	165	$	105
Net income (loss) attributable to noncontrolling interest		1		(7)
Series A Preferred Unit distributions		9		9

Net income available to common units		$	155	$	103

Net income allocable to common units		$	155	$	103
Dilutive effect of Series A Preferred Unit distributions		9		9
Diluted net income allocable to common units		$	164	$	112



Basic weighted average number of common units outstanding (1)		438		437
Dilutive effect of Series A Preferred Units		57		144
Dilutive effect of performance units (2)		—		—
Diluted weighted average number of common units outstanding		495		581

Basic and diluted earnings per unit
Basic		$	0.35	$	0.24
Diluted		$	0.33	$	0.19

____________________

(1)Basic weighted average number of outstanding common units includes approximately two million time-based phantom units for each of the three months ended March 31, 2021 and 2020.

(2)The dilutive effect of the performance unit awards was less than $0.01 per unit during the three months ended March 31, 2021 and 2020.

Partners' Equity (Tables)

3 Months Ended

Mar. 31, 2021

Equity [Abstract]

Schedule of Equity Transactions with Limited Partner

The Partnership paid or has authorized payment of the following cash distributions to common unitholders, as applicable, during 2021 and 2020 (in millions, except for per unit amounts):

Three Months Ended

Record Date

Payment Date

Per Unit Distribution

Total Cash Distribution

March 31, 2021(1)

May 13, 2021

May 25, 2021

0.16525

December 31, 2020

February 22, 2021

March 1, 2021

0.16525

September 30, 2020

November 17, 2020

November 24, 2020

0.16525

June 30, 2020

August 18, 2020

August 25, 2020

0.16525

March 31, 2020

May 19, 2020

May 27, 2020

0.16525

_____________________

(1)The Board of Directors declared a $0.16525 per common unit cash distribution on April 26, 2021, to be paid on May 25, 2021 to common unitholders of record at the close of business on May 13, 2021.

Schedule of Cash Distributions to Series A Preferred Unitholders

The Partnership paid or has authorized payment of the following cash distributions to holders of the Series A Preferred Units during 2021 and 2020 (in millions, except for per unit amounts):

Three Months Ended

Record Date

Payment Date

Per Unit Distribution

Total Cash Distribution

March 31, 2021(1)

April 26, 2021

May 14, 2021

0.5873

December 31, 2020

February 12, 2021

0.625

September 30, 2020

November 3, 2020

November 13, 2020

0.625

June 30, 2020

August 4, 2020

August 14, 2020

0.625

March 31, 2020

May 5, 2020

May 15, 2020

0.625

_____________________

^[1]

[1]	The Board of Directors declared a $0.5873 per Series A Preferred Unit cash distribution on April 26, 2021, to be paid on May 14, 2021, to Series A Preferred unitholders of record at the close of business on April 26, 2021.

Investment in Equity Method Affiliate (Tables)

3 Months Ended

Mar. 31, 2021

Equity Method Investments and Joint Ventures [Abstract]

Schedule of Investments Detail

The following table presents the amount of Equity in earnings of equity method affiliate recognized and Distributions from equity method affiliate received.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Equity in earnings of equity method affiliate		$	1	$	6


Distributions from equity method affiliate (1)		4		10

___________________

The following table includes the summarized financial information of SESH.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Income Statements:
Revenues		$	15	$	27
Operating income		4		16
Net income (loss)		(1)		11

^[1]

[1]	Distributions from equity method affiliate includes a $1 million and $6 million return on investment and a $3 million and $4 million return of investment for the three months ended March 31, 2021 and 2020, respectively.

Debt (Tables)

3 Months Ended

Mar. 31, 2021

Debt Disclosure [Abstract]

Schedule of Debt

The following table presents the Partnership’s outstanding debt.


	March 31, 2021						December 31, 2020
	Outstanding Principal		Discount (1)		Total Debt		Outstanding Principal		Discount (1)		Total Debt

	(In millions)
Commercial Paper	$	214	$	—	$	214	$	250	$	—	$	250

2019 Term Loan Agreement	800		—		800		800		—		800
2024 Notes	600		—		600		600		—		600
2027 Notes	700		(2)		698		700		(2)		698
2028 Notes	800		(4)		796		800		(5)		795
2029 Notes	547		(1)		546		547		(1)		546
2044 Notes	531		—		531		531		—		531
Total debt	$	4,192	$	(7)	$	4,185	$	4,228	$	(8)	$	4,220
Less: Short-term debt (2)					214						250
Less: Current portion of long-term debt (3)					800						—
Less: Unamortized debt expense (4)					19						19
Total long-term debt					$	3,152					$	3,951

____________________

(1)Unamortized discount on long-term debt is amortized over the life of the respective debt.

(2)Short-term debt includes $214 million and $250 million of outstanding commercial paper as of March 31, 2021 and December 31, 2020, respectively.

(3)As of March 31, 2021, Current portion of long-term debt included $800 million outstanding balance of the 2019 Term Loan Agreement.

^{[1],[2],[3],[4]}

[1]	As of March 31, 2021, Current portion of long-term debt included $800 million outstanding balance of the 2019 Term Loan Agreement.
[2]	As of both March 31, 2021 and December 31, 2020, there was an additional $3 million of unamortized debt expense related to the Revolving Credit Facility included in Other assets, not included above.
[3]	Short-term debt includes $214 million and $250 million of outstanding commercial paper as of March 31, 2021 and December 31, 2020, respectively.
[4]	Unamortized discount on long-term debt is amortized over the life of the respective debt.

Derivative Instruments and Hedging Activities (Tables)

3 Months Ended

Mar. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Derivative Instruments

The following table presents the Partnership’s derivative instruments that were not designated as hedging instruments for accounting purposes.


	March 31, 2021		December 31, 2020
	Gross Notional Volume
	Purchases	Sales	Purchases	Sales
Natural gas— TBtu (1)
Financial fixed futures/swaps	1	17	—	18
Financial basis futures/swaps	1	34	—	27
Financial swaptions (2)	—	5	—	7

Crude oil (for condensate)— MBbl (3)
Financial futures/swaps	—	420	—	465
Financial swaptions (2)	—	150	—	90
Natural gas liquids— MBbl (4)
Financial futures/swaps	435	1,155	855	1,210
Financial options	—	30	—	45

____________________

The following table presents the Partnership’s derivative instruments that were designated as hedging instruments for accounting purposes.


	March 31, 2021		December 31, 2020
	Gross Notional Value
	(In millions)
Interest rate swaps	$	300	$	300

^{[1],[2],[3],[4]}

Schedule of Derivative Assets at Fair Value


		March 31, 2021				December 31, 2020
		Fair Value
Instrument	Balance Sheet Location	Assets		Liabilities		Assets		Liabilities

		(In millions)
Natural gas
Financial futures/swaps	Other Current	$	1	$	3	$	2	$	2
Financial swaptions	Other Current	1		2		1		2




Crude oil (for condensate)
Financial futures/swaps	Other Current	—		10		1		13
Financial swaptions	Other Current	—		1		—		—


Natural gas liquids
Financial futures/swaps	Other Current	9		6		15		3
Financial swaptions	Other Current	—		1		—		1

Total gross commodity derivatives (1)		$	11	$	23	$	19	$	21

_____________________

(1)See Note 11 for a reconciliation of the Partnership’s commodity derivatives fair value to the Partnership’s Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020.


		March 31, 2021				December 31, 2020
		Fair Value
Instrument	Balance Sheet Location	Assets		Liabilities		Assets		Liabilities

		(In millions)
Interest rate swaps (1)	Other Current	$	—	$	5	$	—	$	6

_____________________

(1)All interest rate derivative instruments that were designated as cash flow hedges are considered Level 2 as of March 31, 2021 and December 31, 2020.

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value

The following table presents the effect of derivative instruments on the Partnership’s Condensed Consolidated Statements of Income.


		Amounts Recognized in Income
	Three Months Ended March 31,
		2021		2020

		(In millions)
Natural gas
Financial futures/swaps gains (losses)		$	(2)	$	4
Financial swaptions losses		—		(1)
Physical purchases/sales gains		—		1
Crude oil (for condensate)
Financial futures/swaps gains (losses)		(6)		19
Financial swaptions gains (losses)		(1)		4
Natural gas liquids
Financial futures/swaps losses		(5)		(7)
Total		$	(14)	$	20

The following table presents the effect of derivative instruments that were designated as hedging instruments on the Partnership’s Condensed Consolidated Statements of Income.


		Amounts Recognized in Income
	Three Months Ended March 31,
		2021		2020

		(In millions)
Interest rate swaps losses		$	(1)	$	—

Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location

The following table presents the components of gain (loss) on derivative activity in the Partnership’s Condensed Consolidated Statements of Income.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Change in fair value of commodity derivatives		$	(10)	$	10
Realized gain (loss) on commodity derivatives		(4)		10
Gain (loss) on commodity derivative activity		$	(14)	$	20

[1]	As of March 31, 2021, 89.5% of the crude oil (for condensate) contracts had durations of one year or less and 10.5% had durations of more than one year and less than two years. As of December 31, 2020, 100.0% of the crude oil (for condensate) contracts had durations of one year or less.
[2]	As of March 31, 2021, 97.2% of the natural gas liquids contracts had durations of one year or less and 2.8% had durations of more than one year and less than two years. As of December 31, 2020, 100.0% of the natural gas liquids contracts had durations of one year or less.
[3]	As of March 31, 2021, 99.2% of the natural gas contracts had durations of one year or less and 0.8% had durations of more than one year and less than two years. As of December 31, 2020, 95.7% of the natural gas contracts had durations of one year or less and 4.3% had durations of more than one year and less than two years.
[4]	The notional volume contains a combined derivative instrument consisting of a fixed price swap and a sold option, which gives the counterparties the right, but not the obligation, to increase the notional volume hedged under the fixed price swap until the option expiration date. The notional volume represents the volume prior to option exercise.

- Definition

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

+ References

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=121590274&loc=SL5624163-113959

Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=121590274&loc=d3e41620-113959

Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=121590274&loc=SL5579245-113959

Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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-URI http://asc.fasb.org/extlink&oid=121590274&loc=d3e41638-113959

Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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-URI http://asc.fasb.org/extlink&oid=121590274&loc=SL5579240-113959

+ Details

Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2021

Fair Value Disclosures [Abstract]

Schedule of Fair Value and Carrying Amount of Financial Instruments

The following table summarizes the fair value and carrying amount of the Partnership’s financial instruments.


	March 31, 2021				December 31, 2020
	Carrying Amount		Fair Value		Carrying Amount		Fair Value

	(In millions)
Debt
Revolving Credit Facility (Level 2) (1)	$	—	$	—	$	—	$	—
2019 Term Loan Agreement (Level 2)	800		800		800		800
2024 Notes (Level 2)	600		639		600		612
2027 Notes (Level 2)	698		758		698		709
2028 Notes (Level 2)	796		884		795		817
2029 Notes (Level 2)	546		568		546		544
2044 Notes (Level 2)	531		527		531		499

____________________

^[1]

Schedule of Assets and Liabilities Measured at Fair Value on a Recurring Basis

The following tables summarize the Partnership’s other assets and liabilities that are measured at fair value on a recurring basis.


March 31, 2021	Commodity Contracts				Gas Imbalances (1)
	Assets		Liabilities		Assets (2)		Liabilities (3)

	(In millions)
Quoted market prices in active market for identical assets (Level 1)	$	1	$	10	$	—	$	—
Significant other observable inputs (Level 2)	10		13		30		10

Total fair value	11		23		30		10
Netting adjustments	(11)		(11)		—		—
Total	$	—	$	12	$	30	$	10


December 31, 2020	Commodity Contracts				Gas Imbalances (1)
	Assets		Liabilities		Assets (2)		Liabilities (3)

	(In millions)
Quoted market prices in active market for identical assets (Level 1)	$	2	$	14	$	—	$	—
Significant other observable inputs (Level 2)	17		7		23		16

Total fair value	19		21		23		16
Netting adjustments	(19)		(19)		—		—
Total	$	—	$	2	$	23	$	16

______________________

^[2],[3],[4]

[1]	Borrowing capacity is effectively reduced by our borrowings outstanding under the commercial paper program. $214 million and $250 million of commercial paper was outstanding as of March 31, 2021 and December 31, 2020, respectively.
[2]	Gas imbalance assets exclude fuel reserves for under retained fuel due from shippers of $19 million and $19 million at March 31, 2021 and December 31, 2020, respectively, which fuel reserves are based on the value of natural gas at the time the imbalance was created, and which are not subject to revaluation at fair market value.
[3]	Gas imbalance liabilities exclude fuel reserves for over retained fuel due to shippers of $3 million and $3 million at March 31, 2021 and December 31, 2020, respectively, which fuel reserves are based on the value of natural gas at the time the imbalance was created, and which are not subject to revaluation at fair market value.
[4]	The Partnership uses the market approach to fair value its gas imbalance assets and liabilities at individual, or where appropriate an average of, current market indices applicable to the Partnership’s operations, not to exceed net realizable value. There were no netting adjustments as of March 31, 2021 and December 31, 2020.

Supplemental Disclosure of Cash Flow Information (Tables)

3 Months Ended

Mar. 31, 2021

Supplemental Cash Flow Information [Abstract]

Schedule of Cash Flow, Supplemental Disclosures

The following table provides information regarding supplemental cash flow information:


	Three Months Ended March 31,
	2021		2020

	(In millions)
Supplemental Disclosure of Cash Flow Information:
Cash Payments:
Interest, net of capitalized interest	$	32	$	43
Income taxes, net of refunds	(2)		—
Non-cash transactions:
Accounts payable related to capital expenditures	7		8
Lease liabilities related to derecognition of right-of-use assets	—		(4)
Impact of adoption of financial instruments-credit losses accounting standard (Note 1)	—		(3)

Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2021

Schedule of Revenues from Related Parties

The following table presents the amounts of revenues from affiliated companies included in the Partnership’s Condensed Consolidated Statements of Income.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Gas transportation and storage service revenues — CenterPoint Energy		$	27	$	37

Gas transportation and storage service revenues — OGE Energy		10		9
Natural gas product sales — OGE Energy		31		5
Total revenues — affiliated companies		$	68	$	51

Schedule of Natural Gas Purchased From Related Parties

The following table presents the amounts of natural gas purchased from affiliated companies included in the Partnership’s Condensed Consolidated Statements of Income.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Cost of natural gas purchases — CenterPoint Energy		$	—	$	1
Cost of natural gas purchases — OGE Energy		31		8
Total cost of natural gas purchases — affiliated companies		$	31	$	9

Schedule of Amounts Charged to Partnership by Related Parties


	Three Months Ended March 31,
		2021		2020

		(In millions)


Seconded Employee Costs — OGE Energy		$	4	$	3

Equity-Based Compensation (Tables)

3 Months Ended

Mar. 31, 2021

Share-based Payment Arrangement [Abstract]

Disclosure of Share-based Compensation Arrangements by Share-based Payment Award

The following table summarizes the Partnership’s equity-based compensation expense related to performance units and phantom units for the Partnership’s employees and independent directors.


	Three Months Ended March 31,
		2021		2020

		(In millions)
Performance units		$	2	$	2

Phantom units		2		2
Total compensation expense		$	4	$	4

The following table presents the assumptions related to the performance units granted in 2021.


	2021
Number of units granted	1,453,897
Fair value of units granted	$	10.26
Expected distribution yield	12.90		%
Expected price volatility	100.00		%
Risk-free interest rate	0.27		%
Expected life of units (in years)	3

The following table presents the number of phantom units granted and the grant date fair value related to the phantom units granted in 2021.


			2021
Phantom Units granted			1,356,672
Fair value of phantom units granted			$5.41 - $6.87

Schedule of Share-based Compensation, Activity


	Performance Units				Phantom Units
	Number of Units		Weighted Average Grant-Date Fair Value, Per Unit			Number of Units		Weighted Average Grant-Date Fair Value, Per Unit

	(In millions, except unit data)
Units outstanding at December 31, 2020	1,765,508		$	13.10		1,790,845		$	10.29
Granted (1)	1,453,897		10.26			1,356,672		6.86

Vested (2)	(389,817)		17.70			(461,824)		13.11
Forfeited	(32,625)		10.00			(94,669)		8.70
Units outstanding at March 31, 2021	2,796,963		$	11.02		2,591,024		$	8.05
Aggregate intrinsic value of units outstanding at March 31, 2021	$	18				$	17

_____________________

^[1],[2]

Schedule of Unrecognized Compensation Cost, Nonvested Awards


	March 31, 2021
	Unrecognized Compensation Cost (In millions)		Weighted Average Period for Recognition (In years)
Performance Units	$	21	2.25

Phantom Units	14		2.07
Total	$	35

[1]	Performance units represents the target number of performance units granted. The actual number of performance units earned, if any, is dependent upon performance and may range from 0% to 200% of the target.
[2]	Performance units vested as of March 31, 2021 include 389,817 units from the 2018 annual grant, which were approved by the Board of Directors in 2018 and, based on the level of achievement of a performance goal established by the Board of Directors over the performance period of January 1, 2018 through December 31, 2020, no performance units vested.

Reportable Segments (Tables)

3 Months Ended

Mar. 31, 2021

Segment Reporting [Abstract]

Schedule of Financial Data for Business Segments and Services

Financial data for reportable segments are as follows:


Three Months Ended March 31, 2021	Gathering and Processing		Transportation (1) and Storage		Eliminations		Total

	(In millions)
Product sales	$	428	$	332	$	(133)	$	627
Service revenues	196		150		(3)		343
Total Revenues	624		482		(136)		970
Cost of natural gas and natural gas liquids (excluding depreciation and amortization shown separately)	398		257		(136)		519
Operation and maintenance, General and administrative	79		42		—		121
Depreciation and amortization	74		32		—		106

Taxes other than income tax	11		7		—		18
Operating income	$	62	$	144	$	—	$	206
Total Assets	$	10,780	$	5,789	$	(4,805)	$	11,764
Capital expenditures	$	21	$	59	$	—	$	80


Three Months Ended March 31, 2020	Gathering and Processing		Transportation (1) and Storage		Eliminations		Total

	(In millions)
Product sales	$	275	$	75	$	(62)	$	288
Service revenues	202		159		(1)		360
Total Revenues	477		234		(63)		648
Cost of natural gas and natural gas liquids (excluding depreciation and amortization shown separately)	211		78		(63)		226
Operation and maintenance, General and administrative	81		45		—		126
Depreciation and amortization	74		30		—		104
Impairments of property, plant and equipment and goodwill	28		—		—		28
Taxes other than income tax	11		7		—		18
Operating income	$	72	$	74	$	—	$	146
Total assets as of December 31, 2020	$	10,830	$	5,729	$	(4,830)	$	11,729
Capital expenditures	$	34	$	20	$	—	$	54

_____________________

(1)See Note 8 for discussion regarding ownership interests in SESH and related equity earnings included in the transportation and storage segment for the three months ended March 31, 2021 and 2020.

^[1]

[1]	See Note 8 for discussion regarding ownership interests in SESH and related equity earnings included in the transportation and storage segment for the three months ended March 31, 2021 and 2020.

Summary of Significant Accounting Policies - Narrative (Details) $ in Millions			3 Months Ended
	Feb. 17, 2021 USD ($) shares	Apr. 01, 2020 USD ($)	Mar. 31, 2021 USD ($) segment board_member shares	Mar. 31, 2020 USD ($)	Dec. 31, 2020 USD ($)	Jan. 01, 2020 USD ($)	Dec. 31, 2019 USD ($)
Significant Accounting Policies [Line Items]
Number of reportable segments \| segment			2
Number of representatives designated by each of CenterPoint Energy and OGE Energy \| board_member			2
Number of independent board members \| board_member			3
Percentage vote by all unitholders (at least 75%)			75.00%
Merger Termination Fee	$ 97.5
Sale of interest		$ 19.0
Partners' Capital, Including Portion Attributable to Noncontrolling Interest			$ 7,181.0	$ 7,352.0	$ 7,095.0		$ 7,409.0
Accounts receivable			4.0			$ 1.0
Other assets			3.0			3.0
Total Allowance for doubtful accounts			7.0			$ 4.0
Inventory adjustments			$ 1.0	6.0
Partnership Interest
Significant Accounting Policies [Line Items]
Payments to Acquire Businesses, Gross	$ 10.0
Cumulative Effect, Period of Adoption, Adjustment
Significant Accounting Policies [Line Items]
Partners' Capital, Including Portion Attributable to Noncontrolling Interest							(3.0)
Common Unit [Member]
Significant Accounting Policies [Line Items]
Merger Agreement, Right to Receive Number of Common Units Per Share \| shares	0.8595
Series A Preferred Units [Member]
Significant Accounting Policies [Line Items]
Merger Agreement, Right to Receive Number of Common Units Per Share \| shares	0.0265
Atoka
Significant Accounting Policies [Line Items]
Ownership interest (as a percentage)			50.00%
ESCP
Significant Accounting Policies [Line Items]
Ownership interest (as a percentage)			60.00%
OGE Energy \| Partners' Capital
Significant Accounting Policies [Line Items]
Limited partner ownership interest percentage			25.50%
CenterPoint \| Partners' Capital
Significant Accounting Policies [Line Items]
Limited partner ownership interest percentage			53.70%
CenterPoint and OGE Energy \| Partners' Capital
Significant Accounting Policies [Line Items]
Limited partner ownership interest percentage			79.00%
OGE Energy \| Partners' Capital \| Common Unit [Member]
Significant Accounting Policies [Line Items]
Units outstanding \| shares			110,982,805
CenterPoint \| Partners' Capital \| Series A 10% Fixed to Floating Non Cumulative Redeemable Perpetual Preferred Units
Significant Accounting Policies [Line Items]
Series A preferred units held by CenterPoint Energy \| shares			14,520,000
CenterPoint \| Partners' Capital \| Common Unit [Member]
Significant Accounting Policies [Line Items]
Units outstanding \| shares			233,856,623
Partners' Capital \| Common Unit [Member]
Significant Accounting Policies [Line Items]
Partners' Capital, Including Portion Attributable to Noncontrolling Interest			$ 6,798.0	$ 6,972.0	$ 6,713.0		7,013.0
Partners' Capital \| Common Unit [Member] \| Cumulative Effect, Period of Adoption, Adjustment
Significant Accounting Policies [Line Items]
Partners' Capital, Including Portion Attributable to Noncontrolling Interest			$ 0.0				$ (3.0)
Partners' Capital \| OGE Energy
Significant Accounting Policies [Line Items]
Percentage share of management rights			50.00%
Percentage share of incentive distribution rights			60.00%
Partners' Capital \| CenterPoint
Significant Accounting Policies [Line Items]
Percentage share of management rights			50.00%
Percentage share of incentive distribution rights			40.00%

Revenue - Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	$ 641	$ 268
Gain (loss) on derivative activity	(14)	20
Total Revenues	970	648
Natural gas
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	312	69
Natural gas liquids
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	297	172
Condensate Natural Gas
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	32	27
Product
Disaggregation of Revenue [Line Items]
Total Revenues	627	288
Demand Service Revenue
Disaggregation of Revenue [Line Items]
Total Revenues	153	181
Volume Dependant Service Revenue
Disaggregation of Revenue [Line Items]
Total Revenues	190	179
Natural Gas, Gathering, Transportation, Marketing and Processing
Disaggregation of Revenue [Line Items]
Total Revenues	343	360
Operating Segments \| Gathering and Processing
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	441	255
Gain (loss) on derivative activity	(13)	20
Total Revenues	624	477
Operating Segments \| Gathering and Processing \| Natural gas
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	112	56
Operating Segments \| Gathering and Processing \| Natural gas liquids
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	297	172
Operating Segments \| Gathering and Processing \| Condensate Natural Gas
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	32	27
Operating Segments \| Gathering and Processing \| Product
Disaggregation of Revenue [Line Items]
Total Revenues	428	275
Operating Segments \| Gathering and Processing \| Demand Service Revenue
Disaggregation of Revenue [Line Items]
Total Revenues	26	39
Operating Segments \| Gathering and Processing \| Volume Dependant Service Revenue
Disaggregation of Revenue [Line Items]
Total Revenues	170	163
Operating Segments \| Gathering and Processing \| Natural Gas, Gathering, Transportation, Marketing and Processing
Disaggregation of Revenue [Line Items]
Total Revenues	196	202
Operating Segments \| Transportation and Storage
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	333	75
Gain (loss) on derivative activity	(1)	0
Total Revenues	482	234
Operating Segments \| Transportation and Storage \| Natural gas
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	330	73
Operating Segments \| Transportation and Storage \| Natural gas liquids
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	3	2
Operating Segments \| Transportation and Storage \| Condensate Natural Gas
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	0	0
Operating Segments \| Transportation and Storage \| Product
Disaggregation of Revenue [Line Items]
Total Revenues	332	75
Operating Segments \| Transportation and Storage \| Demand Service Revenue
Disaggregation of Revenue [Line Items]
Total Revenues	127	142
Operating Segments \| Transportation and Storage \| Volume Dependant Service Revenue
Disaggregation of Revenue [Line Items]
Total Revenues	23	17
Operating Segments \| Transportation and Storage \| Natural Gas, Gathering, Transportation, Marketing and Processing
Disaggregation of Revenue [Line Items]
Total Revenues	150	159
Eliminations
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	(133)	(62)
Gain (loss) on derivative activity	0	0
Total Revenues	(136)	(63)
Eliminations \| Natural gas
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	(130)	(60)
Eliminations \| Natural gas liquids
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	(3)	(2)
Eliminations \| Condensate Natural Gas
Disaggregation of Revenue [Line Items]
Total revenues from natural gas, natural gas liquids, and condensate	0	0
Eliminations \| Product
Disaggregation of Revenue [Line Items]
Total Revenues	(133)	(62)
Eliminations \| Demand Service Revenue
Disaggregation of Revenue [Line Items]
Total Revenues	0	0
Eliminations \| Volume Dependant Service Revenue
Disaggregation of Revenue [Line Items]
Total Revenues	(3)	(1)
Eliminations \| Natural Gas, Gathering, Transportation, Marketing and Processing
Disaggregation of Revenue [Line Items]
Total Revenues	$ (3)	$ (1)

Revenue - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
Revenue - Narrative (Details) - USD ($) $ in Millions	Jun. 30, 2020	Mar. 31, 2020
Revenue from Contract with Customer [Abstract]
Revenue recognized related to rate case settlement		$ 17
Regulatory Liabilities, Refund to Customers	$ 21

Revenue - Accounts Receivable (Details) - USD ($)
$ in Millions

Mar. 31, 2021

Dec. 31, 2020

Disaggregation of Revenue [Line Items]

Customers

$ 272

$ 245

Contract assets

^[1]

Non-customers

Total Accounts Receivable

^[2]

297

263

Firm Service Transportation [Member]

Disaggregation of Revenue [Line Items]

Contract assets

$ 10

$ 9

[1]

Contract assets reflected in Total Accounts Receivable include accrued minimum volume commitments. Contract assets are primarily attributable to revenues associated with estimated shortfall volumes on certain annual minimum volume commitment arrangements. Total Accounts Receivable does not include contract assets related to firm service transportation contracts with tiered rates of $10 million as of March 31, 2021 and $9 million as of December 31, 2020, which are reflected in Other Assets.

[2]

Total Accounts Receivable includes Accounts receivable, net of allowance for doubtful accounts and Accounts receivable—affiliated companies.

Revenue - Summary of Changes in Contract Liabilities (Details) - USD ($)
$ in Millions

3 Months Ended

12 Months Ended

Mar. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Revenue from Contract with Customer [Abstract]

Contract with Customer, Liability

^[1]

$ 43

$ 44

$ 48

Amounts recognized in revenues related to the beginning balance

(17)

(25)

Net additions

$ 16

$ 21

[1]	Deferred revenues includes deferred revenue—affiliated companies. This amount is included in Other current liabilities and Other long-term liabilities.

Revenue - Summary of Recognition Contract Liabilities (Details)
$ in Millions

3 Months Ended

Mar. 31, 2021

USD ($)

^[1]

Revenue from Contract with Customer [Abstract]

$ 20

$ 2

[1]	Deferred revenues includes deferred revenue—affiliated companies. This amount is included in Other current liabilities and Other long-term liabilities.

Leases - Schedule of Leasing Assets and Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Lessee, Lease, Description [Line Items]
Operating lease asset	$ 24	$ 25
Total lease liabilities	27	28
Other Current Liabilities
Lessee, Lease, Description [Line Items]
Operating Lease, Liability, Current	4	4
Other Liabilities
Lessee, Lease, Description [Line Items]
Operating Lease, Liability, Noncurrent	23	24
Other Assets [Member]
Lessee, Lease, Description [Line Items]
Operating lease asset	$ 24	$ 25

Leases - Summary of Lease Expense (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Lessee, Lease, Description [Line Items]
Weighted average lease term (in years)	6 years 6 months
Weighted average discount rate (as a percentage)	5.49%
Gathering and Processing
Lessee, Lease, Description [Line Items]
Rental costs	$ 4	$ 6
Operating lease cost	1	2
Short-term lease cost	2	3
Variable Lease, Cost	1	1
Total Lease Cost	4	6
Transportation and Storage
Lessee, Lease, Description [Line Items]
Short-term lease cost	0
Field equipment
Lessee, Lease, Description [Line Items]
Rental costs	3	5
Total Lease Cost	3	5
Buildings
Lessee, Lease, Description [Line Items]
Rental costs	1	1
Total Lease Cost	$ 1	$ 1

Leases - Schedule of Operating Lease Obligations Expiration (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Leases [Abstract]
2021 - remainder	$ 4
2022	5
2023	6
2024	4
2025	3
2026	2
After 2026	6
Total	30
Less: impact of the applicable discount rate	3
Total lease liabilities	$ 27	$ 28

Earnings Per Limited Partner Unit (Details) - USD ($)
$ / shares in Units, shares in Millions, $ in Millions

3 Months Ended

Mar. 31, 2021

Mar. 31, 2020

Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]

Net income

$ 165

$ 105

Net income (loss) attributable to noncontrolling interest

(7)

Series A Preferred Unit distributions

Net Income Attributable to Common Units (Note 5)

$ 155

$ 103

Diluted earnings (loss) per unit

Earnings Per Share, Diluted, Undistributed

$ 0.01

Phantom units

Basic weighted average number of outstanding

Basic weighted average number of outstanding

2,000,000

Common Unit [Member]

Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]

Net Income Attributable to Common Units (Note 5)

$ 155

$ 103

Dilutive effect of Series A Preferred Unit distributions

Diluted net income

$ 164

$ 112

Basic weighted average number of outstanding

Basic weighted average number of outstanding

^[1]

438

437

Dilutive effect of Series A Preferred Units (in units)

144

Dilutive effect of performance units (in units)

Diluted weighted average number of outstanding units

^[2]

495

581

Basic and diluted earnings per unit

Basic and diluted earnings per unit

$ 0.35

$ 0.24

Diluted earnings (loss) per unit

Diluted earnings per unit

$ 0.33

$ 0.19

[1]	Basic weighted average number of outstanding common units includes approximately two million time-based phantom units for each of the three months ended March 31, 2021 and 2020.
[2]	The dilutive effect of the performance unit awards was less than $0.01 per unit during the three months ended March 31, 2021 and 2020.

Partners' Equity - Schedule of Cash Distributions (Details) - USD ($)
$ / shares in Units, $ in Millions

May 25, 2021

May 14, 2021

May 13, 2021

Apr. 26, 2021

Mar. 01, 2021

Feb. 22, 2021

Feb. 12, 2021

Nov. 24, 2020

Nov. 17, 2020

Nov. 13, 2020

Nov. 03, 2020

Aug. 25, 2020

^[1]

Aug. 18, 2020

^[1]

Aug. 14, 2020

^[2]

Aug. 04, 2020

^[2]

May 27, 2020

May 19, 2020

May 15, 2020

May 05, 2020

Distribution Made to Limited Partner [Line Items]

Record Date

Feb. 22, 2021

Nov. 17, 2020

Aug. 18, 2020

May 19, 2020

Payment Date

Mar. 01, 2021

Nov. 24, 2020

Aug. 25, 2020

May 27, 2020

Series A 10% Fixed to Floating Non Cumulative Redeemable Perpetual Preferred Units | Preferred Units

Distribution Made to Limited Partner [Line Items]

Record Date

Feb. 12, 2021

Nov. 03, 2020

Aug. 04, 2020

May 05, 2020

Payment Date

Feb. 12, 2021

Nov. 13, 2020

Aug. 14, 2020

May 15, 2020

Cash Distribution

Distribution Made to Limited Partner [Line Items]

Cash distribution (in dollars per unit)

$ 0.16525

Cash distribution made to unitholders

$ 72

Cash Distribution | Series A 10% Fixed to Floating Non Cumulative Redeemable Perpetual Preferred Units | Preferred Units

Distribution Made to Limited Partner [Line Items]

Cash distribution (in dollars per unit)

$ 0.625

Cash distribution made to unitholders

$ 9

Forecast | Subsequent Event

Distribution Made to Limited Partner [Line Items]

Record Date

May 13, 2021

Payment Date

May 25, 2021

Forecast | Subsequent Event | Series A 10% Fixed to Floating Non Cumulative Redeemable Perpetual Preferred Units | Preferred Units

Distribution Made to Limited Partner [Line Items]

Record Date

Apr. 26, 2021

Payment Date

May 14, 2021

Forecast | Subsequent Event | Cash Distribution

Distribution Made to Limited Partner [Line Items]

Cash distribution declared (in dollars per unit)

$ 0.16525

Cash distribution declared to unitholders

$ 72

Forecast | Subsequent Event | Cash Distribution | Series A 10% Fixed to Floating Non Cumulative Redeemable Perpetual Preferred Units | Preferred Units

Distribution Made to Limited Partner [Line Items]

Cash distribution declared (in dollars per unit)

$ 0.5873

Cash distribution declared to unitholders

$ 9

[1]	The Board of Directors declared a $0.16525 per common unit cash distribution on April 26, 2021, to be paid on May 25, 2021 to common unitholders of record at the close of business on May 13, 2021.
[2]	The Board of Directors declared a $0.5873 per Series A Preferred Unit cash distribution on April 26, 2021, to be paid on May 14, 2021, to Series A Preferred unitholders of record at the close of business on April 26, 2021.

Partners' Equity - Narrative (Details) - $ / shares		1 Months Ended	3 Months Ended
Partners' Equity - Narrative (Details) - $ / shares	Feb. 18, 2016	Mar. 31, 2021	Mar. 31, 2021
Distribution Made to Limited Partner [Line Items]
Limited partners' capital account, required quarterly distribution period			60 days
Series A 10% Fixed to Floating Non Cumulative Redeemable Perpetual Preferred Units
Distribution Made to Limited Partner [Line Items]
Annual percentage rate	10.00%	8.7375%
Liquidation preference (in dollars per share)	$ 25.00
Duration of cash distributions	5 years
Preferred units liquidation spread			8.50%

Impairment of Long-Lived Assets (Details) - Atoka - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Impaired Long-Lived Assets Held and Used [Line Items]
Ownership interest (as a percentage)	50.00%
Gathering and Processing
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of long-lived assets		$ 16

Impairment of Goodwill (Details) - USD ($) $ in Millions	3 Months Ended
Impairment of Goodwill (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2017	Mar. 31, 2021	Dec. 31, 2020
Goodwill [Line Items]
Goodwill			$ 0	$ 0
Gathering and Processing
Goodwill [Line Items]
Goodwill acquired		$ 12
Goodwill impairment	$ (12)

Investment in Equity Method Affiliate - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Schedule of Equity Method Investments [Line Items]
Amount billed associated with service agreements	$ 970	$ 648
SESH
Schedule of Equity Method Investments [Line Items]
Percentage of distributions through limited partner interest	50.00%
SESH \| Enbridge, Inc. [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage	50.00%
SESH \| Enable Midstream Partners, LP [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage	50.00%
SESH \| Equity Method Investee \| Shared Operations Service Agreements
Schedule of Equity Method Investments [Line Items]
Amount billed associated with service agreements	$ 2	$ 6

- Definition

Amount, excluding tax collected from customer, of revenue from satisfaction of performance obligation by transferring promised good or service to customer. Tax collected from customer is tax assessed by governmental authority that is both imposed on and concurrent with specific revenue-producing transaction, including, but not limited to, sales, use, value added and excise.

+ References

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+ Details

Investment in Equity Method Affiliate - Schedule of Investments (Details) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2021

Mar. 31, 2020

Equity Method Affiliates Reported Amounts:

Return on investment in equity method affiliate

$ 1

$ 6

Return of investment in equity method affiliate

Operating income

206

146

Net Income (Loss)

165

105

SESH

Equity Method Affiliates Reported Amounts:

Equity in earnings of equity method affiliate

Distributions from equity method affiliate (1)

^[1]

Return on investment in equity method affiliate

Return of investment in equity method affiliate

Revenues

Operating income

Net Income (Loss)

$ (1)

$ 11

[1]	Distributions from equity method affiliate includes a $1 million and $6 million return on investment and a $3 million and $4 million return of investment for the three months ended March 31, 2021 and 2020, respectively.

- Definition

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

+ References

+ Details

- Definition

Amount of revenue recognized from goods sold, services rendered, insurance premiums, or other activities that constitute an earning process. Includes, but is not limited to, investment and interest income before deduction of interest expense when recognized as a component of revenue, and sales and trading gain (loss).

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-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03(1))
-URI http://asc.fasb.org/extlink&oid=120395209&loc=SL114868664-224227

+ Details

Debt - Schedule of Outstanding Debt (Details) - USD ($)

Mar. 31, 2021

Dec. 31, 2020

Debt Instrument [Line Items]

Short-term debt

$ 214,000,000

$ 250,000,000

Outstanding Principal

4,192,000,000

4,228,000,000

Discount

^[1]

(7,000,000)

(8,000,000)

Total Debt

4,185,000,000

4,220,000,000

Less: Unamortized debt expense

^[2]

(19,000,000)

Total long-term debt

3,152,000,000

3,951,000,000

2019 Term Loan Agreement | 2019 Term Loan Agreement

Debt Instrument [Line Items]

Outstanding Principal

800,000,000

Discount

^[1]

Total Debt

800,000,000

Senior Notes | 2024 Notes

Debt Instrument [Line Items]

Outstanding Principal

600,000,000

Discount

^[1]

Total Debt

600,000,000

Senior Notes | 2027 Notes

Debt Instrument [Line Items]

Outstanding Principal

700,000,000

Discount

^[1]

(2,000,000)

Total Debt

698,000,000

Senior Notes | 2028 Notes

Debt Instrument [Line Items]

Outstanding Principal

800,000,000

Discount

^[1]

(4,000,000)

(5,000,000)

Total Debt

796,000,000

795,000,000

Senior Notes | 2029 Notes

Debt Instrument [Line Items]

Outstanding Principal

547,000,000

Discount

^[1]

(1,000,000)

Total Debt

546,000,000

Senior Notes | 2044 Notes

Debt Instrument [Line Items]

Outstanding Principal

531,000,000

Discount

^[1]

Total Debt

531,000,000

Senior Notes | Senior notes due in 2020

Debt Instrument [Line Items]

Less: Current portion of long-term debt

^[3]

800,000,000

Revolving Credit Facility

Debt Instrument [Line Items]

Unamortized debt expense related to Revolving Credit Facility

3,000,000

Commercial Paper

Debt Instrument [Line Items]

Short-term debt

^[4]

214,000,000

250,000,000

Discount

^[1]

$ 0

[1]	Unamortized discount on long-term debt is amortized over the life of the respective debt.
[2]	As of both March 31, 2021 and December 31, 2020, there was an additional $3 million of unamortized debt expense related to the Revolving Credit Facility included in Other assets, not included above.
[3]	As of March 31, 2021, Current portion of long-term debt included $800 million outstanding balance of the 2019 Term Loan Agreement.
[4]	Short-term debt includes $214 million and $250 million of outstanding commercial paper as of March 31, 2021 and December 31, 2020, respectively.

Debt - Narrative (Details)

3 Months Ended

Jan. 29, 2019

USD ($)

Apr. 06, 2018

USD ($)

Mar. 31, 2021

USD ($)

Dec. 31, 2020

USD ($)

Debt Instrument [Line Items]

Commercial paper, authorized

$ 1,400,000,000

Commercial paper

$ 214,000,000

$ 250,000,000

2019 Term Loan Agreement

Debt Instrument [Line Items]

Weighted average interest rate percentage

2.08%

Number of times option maybe exercised to extend term of Term Loan Facility

Debt Instrument, Term of Extension Period

1 year

Debt Instrument, Principle Advance

$ 800,000,000

LIBOR | 2019 Term Loan Agreement

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

1.25%

Minimum | Eurodollar | 2019 Term Loan Agreement

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

0.75%

Minimum | Base Rate | 2019 Term Loan Agreement

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

0.00%

Maximum | Eurodollar | 2019 Term Loan Agreement

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

1.50%

Maximum | Base Rate | 2019 Term Loan Agreement

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

0.50%

Senior Notes | Senior Notes including 2024 Notes, 2027 Notes, 2028 Notes, 2029 Notes and 2044 Notes

Debt Instrument [Line Items]

Debt Instrument, Unamortized discount

$ 7,000,000

Debt Instrument, Debt Issuance Costs, Net

$ 19,000,000

Senior Notes | 2024 Notes

Debt Instrument [Line Items]

Debt Instrument, Interest Rate During Period

4.01%

Senior Notes | 2027 Notes

Debt Instrument [Line Items]

Debt Instrument, Interest Rate During Period

4.56%

Senior Notes | 2028 Notes

Debt Instrument [Line Items]

Debt Instrument, Interest Rate During Period

5.19%

Senior Notes | 2029 Notes

Debt Instrument [Line Items]

Debt Instrument, Interest Rate During Period

4.30%

Senior Notes | 2044 Notes

Debt Instrument [Line Items]

Debt Instrument, Interest Rate During Period

5.08%

Revolving Credit Facility

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 1,750,000,000

Duration of term loan facility (in years)

5 years

Increase in maximum borrowing capacity

$ 875,000,000

Number of times option maybe exercised to extend term of Term Loan Facility

Debt Instrument, Term of Extension Period

1 year

Letters of credit principal advances

$ 0

Letters of credit outstanding amount

3,000,000

Remaining borrowing capacity

$ 980,000,000

Commitment fee percentage

0.20%

Revolving Credit Facility | LIBOR

Debt Instrument [Line Items]

Applicable margin percentage

1.50%

Commercial Paper

Debt Instrument [Line Items]

Commercial paper

^[1]

$ 214,000,000

$ 250,000,000

Weighted average interest rate percentage

0.73%

[1]	Short-term debt includes $214 million and $250 million of outstanding commercial paper as of March 31, 2021 and December 31, 2020, respectively.

Derivative Instruments and Hedging Activities Quantitative Disclosures Related to Derivative Instruments (Details) - Not Designated as Hedging Instrument
bbl in Thousands, MMBTU in Millions

3 Months Ended

12 Months Ended

Mar. 31, 2021

MMBTU

bbl

Dec. 31, 2020

MMBTU

bbl

Natural gas, Financial fixed futures/swaps | Purchases

Derivative [Line Items]

Derivative, gross notional volume (TBtu) | MMBTU

^[1]

Natural gas, Financial fixed futures/swaps | Sales

Derivative [Line Items]

Derivative, gross notional volume (TBtu) | MMBTU

^[1]

Natural gas, Financial basis futures/swaps | Purchases

Derivative [Line Items]

Derivative, gross notional volume (TBtu) | MMBTU

^[1]

Natural gas, Financial basis futures/swaps | Sales

Derivative [Line Items]

Derivative, gross notional volume (TBtu) | MMBTU

^[1]

Natural gas, Financial swaptions | Purchases

Derivative [Line Items]

Derivative, gross notional volume (TBtu) | MMBTU

^[1],[2]

Natural gas, Financial swaptions | Sales

Derivative [Line Items]

Derivative, gross notional volume (TBtu) | MMBTU

^[1],[2]

Crude oil, Financial Futures/swaps | Purchases

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount, Volume

^[3]

Crude oil, Financial Futures/swaps | Sales

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount, Volume

^[3]

420

465

Crude oil, Financial options | Purchases

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount, Volume

^[2],[3]

Crude oil, Financial options | Sales

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount, Volume

^[2],[3]

150

Natural gas liquids, Financial Futures/swaps | Purchases

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount, Volume

^[4]

435

855

Natural gas liquids, Financial Futures/swaps | Sales

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount, Volume

^[4]

1,155

1,210

Natural gas liquids, Options | Purchases

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount, Volume

^[4]

Natural gas liquids, Options | Sales

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount, Volume

^[4]

Natural gas

Derivative [Line Items]

Percent of contract with durations of one year or less

99.20%

95.70%

Percent of contracts with durations of more than one year and less than two years

0.80%

4.30%

Crude oil (for condensate)

Derivative [Line Items]

Percent of contract with durations of one year or less

89.50%

100.00%

Percent of contracts with durations of more than one year and less than two years

10.50%

Natural gas liquids

Derivative [Line Items]

Percent of contract with durations of one year or less

97.20%

100.00%

Percent of contracts with durations of more than one year and less than two years

2.80%

[1]	As of March 31, 2021, 99.2% of the natural gas contracts had durations of one year or less and 0.8% had durations of more than one year and less than two years. As of December 31, 2020, 95.7% of the natural gas contracts had durations of one year or less and 4.3% had durations of more than one year and less than two years.
[2]	The notional volume contains a combined derivative instrument consisting of a fixed price swap and a sold option, which gives the counterparties the right, but not the obligation, to increase the notional volume hedged under the fixed price swap until the option expiration date. The notional volume represents the volume prior to option exercise.
[3]	As of March 31, 2021, 89.5% of the crude oil (for condensate) contracts had durations of one year or less and 10.5% had durations of more than one year and less than two years. As of December 31, 2020, 100.0% of the crude oil (for condensate) contracts had durations of one year or less.
[4]	As of March 31, 2021, 97.2% of the natural gas liquids contracts had durations of one year or less and 2.8% had durations of more than one year and less than two years. As of December 31, 2020, 100.0% of the natural gas liquids contracts had durations of one year or less.

Derivative Instruments and Hedging Activities - Derivative Instruments Designated as Hedging Instruments (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Designated as Hedging Instrument \| Interest Rate Swap
Derivative [Line Items]
Interest rate swaps	$ 300	$ 300

Derivative Instruments and Hedging Activities - Balance Sheet Location (Details) - USD ($)
$ in Millions

Mar. 31, 2021

Dec. 31, 2020

Not Designated as Hedging Instrument

Derivatives, Fair Value [Line Items]

Derivative asset

^[1]

$ 11

$ 19

Derivative liability

^[1]

Interest rate swaps | Designated as Hedging Instrument | Other Current Assets

Derivatives, Fair Value [Line Items]

Derivative asset

^[2]

Interest rate swaps | Designated as Hedging Instrument | Other Current Liabilities

Derivatives, Fair Value [Line Items]

Derivative liability

^[2]

Natural gas | Financial futures/swaps | Not Designated as Hedging Instrument | Other Current Assets

Derivatives, Fair Value [Line Items]

Derivative asset

Natural gas | Financial futures/swaps | Not Designated as Hedging Instrument | Other Current Liabilities

Derivatives, Fair Value [Line Items]

Derivative liability

Natural gas | Financial swaptions | Not Designated as Hedging Instrument | Other Current Assets

Derivatives, Fair Value [Line Items]

Derivative asset

Natural gas | Financial swaptions | Not Designated as Hedging Instrument | Other Current Liabilities

Derivatives, Fair Value [Line Items]

Derivative liability

Crude oil (for condensate) | Financial futures/swaps | Not Designated as Hedging Instrument | Other Current Assets

Derivatives, Fair Value [Line Items]

Derivative asset

Crude oil (for condensate) | Financial futures/swaps | Not Designated as Hedging Instrument | Other Current Liabilities

Derivatives, Fair Value [Line Items]

Derivative liability

Crude oil (for condensate) | Financial swaptions | Not Designated as Hedging Instrument | Other Current Assets

Derivatives, Fair Value [Line Items]

Derivative asset

Crude oil (for condensate) | Financial swaptions | Not Designated as Hedging Instrument | Other Current Liabilities

Derivatives, Fair Value [Line Items]

Derivative liability

Natural gas liquids | Financial futures/swaps | Not Designated as Hedging Instrument | Other Current Assets

Derivatives, Fair Value [Line Items]

Derivative asset

Natural gas liquids | Financial futures/swaps | Not Designated as Hedging Instrument | Other Current Liabilities

Derivatives, Fair Value [Line Items]

Derivative liability

Natural gas liquids | Financial swaptions | Not Designated as Hedging Instrument | Other Current Assets

Derivatives, Fair Value [Line Items]

Derivative asset

Natural gas liquids | Financial swaptions | Not Designated as Hedging Instrument | Other Current Liabilities

Derivatives, Fair Value [Line Items]

Derivative liability

$ 1

[1]	See Note 11 for a reconciliation of the Partnership’s commodity derivatives fair value to the Partnership’s Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020.
[2]	All interest rate derivative instruments that were designated as cash flow hedges are considered Level 2 as of March 31, 2021 and December 31, 2020.

Derivative Instruments and Hedging Activities - Amounts Recognized in Income (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Derivative Instruments, Gain (Loss) [Line Items]
Change in fair value of commodity derivatives	$ (10)	$ 10
Realized gain (loss) on commodity derivatives	(4)	10
Gain (loss) on commodity derivative activity	(14)	20
Cash collateral posted	0
Cash collateral required if ratings are lowered	1
Interest Rate Swap
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate swaps losses	(1)	0
Natural gas \| Financial futures/swaps
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on commodity derivative activity	(2)	4
Natural gas \| Financial swaptions
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on commodity derivative activity	0	(1)
Natural gas \| Natural gas, Physical purchases/sales
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on commodity derivative activity	0	1
Condensate \| Financial futures/swaps
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on commodity derivative activity	(6)	19
Condensate \| Financial swaptions
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on commodity derivative activity	(1)	4
Natural gas liquids \| Financial futures/swaps
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on commodity derivative activity	$ (5)	$ (7)

Fair Value Measurements - Carrying and Fair Value Amounts (Details) - USD ($)

Mar. 31, 2021

Dec. 31, 2020

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Commercial paper

$ 214,000,000

$ 250,000,000

Carrying Amount | Significant other observable inputs (Level 2) | Revolving Credit Facility

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Revolving Credit Facility (Level 2)

^[1]

Carrying Amount | Significant other observable inputs (Level 2) | 2019 Term Loan Agreement | 2019 Term Loan Agreement

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

2019 Term Loan Agreement (Level 2)

800,000,000

Carrying Amount | Significant other observable inputs (Level 2) | Senior Notes | 2024 Notes

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Senior Notes (Level 2)

600,000,000

Carrying Amount | Significant other observable inputs (Level 2) | Senior Notes | 2027 Notes

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Senior Notes (Level 2)

698,000,000

Carrying Amount | Significant other observable inputs (Level 2) | Senior Notes | 2028 Notes

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Senior Notes (Level 2)

796,000,000

795,000,000

Carrying Amount | Significant other observable inputs (Level 2) | Senior Notes | 2029 Notes

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Senior Notes (Level 2)

546,000,000

Carrying Amount | Significant other observable inputs (Level 2) | Senior Notes | 2044 Notes

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Senior Notes (Level 2)

531,000,000

Fair Value | Significant other observable inputs (Level 2) | Revolving Credit Facility

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Revolving Credit Facility (Level 2)

^[1]

Fair Value | Significant other observable inputs (Level 2) | 2019 Term Loan Agreement | 2019 Term Loan Agreement

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

2019 Term Loan Agreement (Level 2)

800,000,000

Fair Value | Significant other observable inputs (Level 2) | Senior Notes | 2024 Notes

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Senior Notes (Level 2)

639,000,000

612,000,000

Fair Value | Significant other observable inputs (Level 2) | Senior Notes | 2027 Notes

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Senior Notes (Level 2)

758,000,000

709,000,000

Fair Value | Significant other observable inputs (Level 2) | Senior Notes | 2028 Notes

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Senior Notes (Level 2)

884,000,000

817,000,000

Fair Value | Significant other observable inputs (Level 2) | Senior Notes | 2029 Notes

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Senior Notes (Level 2)

568,000,000

544,000,000

Fair Value | Significant other observable inputs (Level 2) | Senior Notes | 2044 Notes

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Senior Notes (Level 2)

527,000,000

499,000,000

Commercial Paper

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Commercial paper

^[2]

$ 214,000,000

$ 250,000,000

[1]	Borrowing capacity is effectively reduced by our borrowings outstanding under the commercial paper program. $214 million and $250 million of commercial paper was outstanding as of March 31, 2021 and December 31, 2020, respectively.
[2]	Short-term debt includes $214 million and $250 million of outstanding commercial paper as of March 31, 2021 and December 31, 2020, respectively.

Fair Value Measurements - Fair Value Hierarchy (Details) - USD ($)
$ in Millions

Mar. 31, 2021

Dec. 31, 2020

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Retained fuel due from shippers

$ 19

Retained fuel due to shippers

Commodity Contracts | Recurring Measurement

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Assets, total fair value

Liabilities, total fair value

Asset netting adjustments

(11)

(19)

Liability netting adjustments

(11)

(19)

Total assets

Total Liabilities

Commodity Contracts | Recurring Measurement | Quoted market prices in active market for identical assets (Level 1)

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Assets

Liabilities

Commodity Contracts | Recurring Measurement | Significant other observable inputs (Level 2)

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Assets

Liabilities

Gas Imbalances | Recurring Measurement

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Assets, total fair value

^[1],[2]

Liabilities, total fair value

^[2],[3]

Asset netting adjustments

^[1],[2]

Liability netting adjustments

^[2],[3]

Total assets

^[1],[2]

Total Liabilities

^[2],[3]

Gas Imbalances | Recurring Measurement | Quoted market prices in active market for identical assets (Level 1)

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Assets

^[1],[2]

Liabilities

^[2],[3]

Gas Imbalances | Recurring Measurement | Significant other observable inputs (Level 2)

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Assets

^[1],[2]

Liabilities

^[2],[3]

$ 10

$ 16

[1]	Gas imbalance assets exclude fuel reserves for under retained fuel due from shippers of $19 million and $19 million at March 31, 2021 and December 31, 2020, respectively, which fuel reserves are based on the value of natural gas at the time the imbalance was created, and which are not subject to revaluation at fair market value.
[2]	The Partnership uses the market approach to fair value its gas imbalance assets and liabilities at individual, or where appropriate an average of, current market indices applicable to the Partnership’s operations, not to exceed net realizable value. There were no netting adjustments as of March 31, 2021 and December 31, 2020.
[3]	Gas imbalance liabilities exclude fuel reserves for over retained fuel due to shippers of $3 million and $3 million at March 31, 2021 and December 31, 2020, respectively, which fuel reserves are based on the value of natural gas at the time the imbalance was created, and which are not subject to revaluation at fair market value.

Supplemental Disclosure of Cash Flow Information - Supplemental Disclosure of Cash Flow Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2019
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Interest, net of capitalized interest	$ 32	$ 43
Income Taxes Paid, Net	(2)	0
Accounts payable related to capital expenditures	7	8
Lease liabilities related to derecognition of right-of-use assets	0	4
Partners' Capital, Including Portion Attributable to Noncontrolling Interest	7,181	7,352	$ 7,095	$ 7,409
Common Unit [Member] \| Partners' Capital
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Partners' Capital, Including Portion Attributable to Noncontrolling Interest	6,798	$ 6,972	$ 6,713	7,013
Cumulative Effect, Period of Adoption, Adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Partners' Capital, Including Portion Attributable to Noncontrolling Interest				(3)
Cumulative Effect, Period of Adoption, Adjustment \| Common Unit [Member] \| Partners' Capital
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Partners' Capital, Including Portion Attributable to Noncontrolling Interest	$ 0			$ (3)

Related Party Transactions - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Related Party Transaction [Line Items]
Partnership's revenues from affiliated companies as a percent of total revenues	7.00%	8.00%
Subsidiary of Common Parent \| CenterPoint \| Three Services Included in Transportation and Storage Agreements
Related Party Transaction [Line Items]
Period of written notice	180 days
CenterPoint and OGE Energy \| Minimum
Related Party Transaction [Line Items]
Period notice of termination for reimbursements for all employee costs	90 days
OGE Energy \| Defined Benefit and Retiree Medical Plans
Related Party Transaction [Line Items]
Expense reimbursement, 2018 and thereafter	$ 5
OGE Energy \| Certain Services and Support Functions
Related Party Transaction [Line Items]
Expense reimbursement annual caps	1
CenterPoint \| Certain Services and Support Functions
Related Party Transaction [Line Items]
Expense reimbursement annual caps	$ 1

Related Party Transactions - Related Party Activity (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Related Party Transaction [Line Items]
Revenues from affiliated companies	$ 68	$ 51
Cost of natural gas purchases from affiliated companies	31	9
CenterPoint
Related Party Transaction [Line Items]
Cost of natural gas purchases from affiliated companies	0	1
CenterPoint \| Gas Transportation and Storage
Related Party Transaction [Line Items]
Revenues from affiliated companies	27	37
OGE Energy
Related Party Transaction [Line Items]
Cost of natural gas purchases from affiliated companies	31	8
OGE Energy \| Gas Transportation and Storage
Related Party Transaction [Line Items]
Revenues from affiliated companies	10	9
OGE Energy \| Gas Sales
Related Party Transaction [Line Items]
Revenues from affiliated companies	31	5
OGE Energy \| Seconded Employee Costs
Related Party Transaction [Line Items]
Seconded employee costs	$ 4	$ 3

Commitments and Contingencies (Details) - USD ($) $ in Millions	Sep. 13, 2018	Jan. 01, 2017	Mar. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Gathering and processing agreement term (in years)		10 years
Minimum volume commitment fee			$ 164
Minimum volume commitment fees remaining in current year			15
Minimum volume commitment fees per year from 2022 through 2027			23
Minimum volume commitment fees in 2028			11
Estimated Cost to Complete Pipeline Project			$ 540
Firm transportation service agreement term (in years)	20 years

Equity-Based Compensation (Details) - USD ($) $ in Millions	3 Months Ended
Equity-Based Compensation (Details) - USD ($) $ in Millions	Mar. 31, 2021	Mar. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	$ 4	$ 4
Performance units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	2	2
Phantom units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	$ 2	$ 2

Equity-Based Compensation - Performance Units (Details) - Performance units

3 Months Ended

Mar. 31, 2021

$ / shares

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Number of units granted | shares

1,453,897

^[1]

Fair value of units granted | $ / shares

$ 10.26

^[1]

Expected distribution yield

12.90%

Expected price volatility

100.00%

Risk-free interest rate

0.27%

Expected life of units (in years)

3 years

[1]	Performance units represents the target number of performance units granted. The actual number of performance units earned, if any, is dependent upon performance and may range from 0% to 200% of the target.

Equity-Based Compensation - Phantom Units (Details) - Phantom units

3 Months Ended

Mar. 31, 2021

$ / shares

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Phantom Units granted | shares

1,356,672

^[1]

Fair value of phantom units granted (in dollars per share)

$ 6.86

^[1]

Minimum

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Fair value of phantom units granted (in dollars per share)

5.41

Maximum

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Fair value of phantom units granted (in dollars per share)

$ 6.87

[1]	Performance units represents the target number of performance units granted. The actual number of performance units earned, if any, is dependent upon performance and may range from 0% to 200% of the target.

Equity-Based Compensation - Equity Units Activity (Details)
$ / shares in Units, $ in Millions

3 Months Ended

Mar. 31, 2021

USD ($)

$ / shares

Performance units

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]

Units Outstanding (in units) | shares

1,765,508

Granted (in units) | shares

1,453,897

^[1]

Vested (in units) | shares

(389,817)

^[2]

Forfeited (in units) | shares

(32,625)

Units Outstanding (in units) | shares

2,796,963

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]

Units Outstanding (in dollars per unit)

$ 13.10

Granted (in dollars per unit)

10.26

^[1]

Vested (in dollars per unit)

17.70

^[2]

Forfeited (in dollars per unit)

10.00

Units Outstanding (in dollars per unit)

$ 11.02

Aggregate Intrinsic Value of Units Outstanding | $

$ 18

Performance units | Minimum

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]

Payout percentage

0.00%

Performance units | Maximum

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]

Payout percentage

200.00%

Performance units | Annual Grant in 2018 [Member]

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]

Granted (in units) | shares

389,817

Phantom units

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]

Units Outstanding (in units) | shares

1,790,845

Granted (in units) | shares

1,356,672

^[1]

Vested (in units) | shares

(461,824)

^[2]

Forfeited (in units) | shares

(94,669)

Units Outstanding (in units) | shares

2,591,024

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]

Units Outstanding (in dollars per unit)

$ 10.29

Granted (in dollars per unit)

6.86

^[1]

Vested (in dollars per unit)

13.11

^[2]

Forfeited (in dollars per unit)

8.70

Units Outstanding (in dollars per unit)

$ 8.05

Aggregate Intrinsic Value of Units Outstanding | $

$ 17

Phantom units | Minimum

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]

Granted (in dollars per unit)

$ 5.41

Phantom units | Maximum

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]

Granted (in dollars per unit)

$ 6.87

[1]	Performance units represents the target number of performance units granted. The actual number of performance units earned, if any, is dependent upon performance and may range from 0% to 200% of the target.
[2]	Performance units vested as of March 31, 2021 include 389,817 units from the 2018 annual grant, which were approved by the Board of Directors in 2018 and, based on the level of achievement of a performance goal established by the Board of Directors over the performance period of January 1, 2018 through December 31, 2020, no performance units vested.

Equity-Based Compensation - Unrecognized Compensation Cost (Details) $ in Millions	3 Months Ended
	Mar. 31, 2021 USD ($) shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost (In millions)	$ 35
Performance units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost (In millions)	$ 21
Weighted Average Period for Recognition (In years)	2 years 3 months
Phantom units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost (In millions)	$ 14
Weighted Average Period for Recognition (In years)	2 years 25 days
Long Term Incentive Plan \| Common Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares available for issuance \| shares	3,105,706

Reportable Segments - Schedule of Financial Data for Business Segments and Services (Details) $ in Millions	3 Months Ended
	Mar. 31, 2021 USD ($) segment	Mar. 31, 2020 USD ($)	Dec. 31, 2020 USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments \| segment	2
Total Revenues	$ 970	$ 648
Cost of natural gas and natural gas liquids (excluding depreciation and amortization shown separately)	519	226
Operation and maintenance, General and administrative	121	126
Depreciation and amortization	106	104
Impairments of property, plant and equipment and goodwill	0	28
Taxes other than income tax	18	18
Operating Income	206	146
Total assets	11,764		$ 11,729
Capital expenditures	80	54
Operating Segments \| Gathering and Processing
Segment Reporting Information [Line Items]
Total Revenues	624	477
Cost of natural gas and natural gas liquids (excluding depreciation and amortization shown separately)	398	211
Operation and maintenance, General and administrative	79	81
Depreciation and amortization	74	74
Impairments of property, plant and equipment and goodwill		28
Taxes other than income tax	11	11
Operating Income	62	72
Total assets	10,780		10,830
Capital expenditures	21	34
Operating Segments \| Transportation and Storage
Segment Reporting Information [Line Items]
Total Revenues	482	234
Cost of natural gas and natural gas liquids (excluding depreciation and amortization shown separately)	257	78
Operation and maintenance, General and administrative	42	45
Depreciation and amortization	32	30
Impairments of property, plant and equipment and goodwill		0
Taxes other than income tax	7	7
Operating Income	144	74
Total assets	5,789		5,729
Capital expenditures	59	20
Eliminations
Segment Reporting Information [Line Items]
Total Revenues	(136)	(63)
Cost of natural gas and natural gas liquids (excluding depreciation and amortization shown separately)	(136)	(63)
Operation and maintenance, General and administrative	0	0
Depreciation and amortization	0	0
Impairments of property, plant and equipment and goodwill		0
Taxes other than income tax	0	0
Operating Income	0	0
Total assets	(4,805)		$ (4,830)
Capital expenditures	0	0
Product
Segment Reporting Information [Line Items]
Total Revenues	627	288
Product \| Operating Segments \| Gathering and Processing
Segment Reporting Information [Line Items]
Total Revenues	428	275
Product \| Operating Segments \| Transportation and Storage
Segment Reporting Information [Line Items]
Total Revenues	332	75
Product \| Eliminations
Segment Reporting Information [Line Items]
Total Revenues	(133)	(62)
Natural Gas, Gathering, Transportation, Marketing and Processing
Segment Reporting Information [Line Items]
Total Revenues	343	360
Natural Gas, Gathering, Transportation, Marketing and Processing \| Operating Segments \| Gathering and Processing
Segment Reporting Information [Line Items]
Total Revenues	196	202
Natural Gas, Gathering, Transportation, Marketing and Processing \| Operating Segments \| Transportation and Storage
Segment Reporting Information [Line Items]
Total Revenues	150	159
Natural Gas, Gathering, Transportation, Marketing and Processing \| Eliminations
Segment Reporting Information [Line Items]
Total Revenues	$ (3)	$ (1)

Revenue - Summary of Recognition of Remaining Performance Obligations (Details) $ in Millions	Mar. 31, 2021 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	9 months
Total remaining performance obligations	$ 418
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-04-01 \| Transportation and Storage
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	9 months
Total remaining performance obligations	$ 325
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-04-01 \| Gathering and Processing
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	9 months
Total remaining performance obligations	$ 93
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Total remaining performance obligations	$ 516
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 \| Transportation and Storage
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Total remaining performance obligations	$ 393
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 \| Gathering and Processing
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Total remaining performance obligations	$ 123
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Total remaining performance obligations	$ 474
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 \| Transportation and Storage
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Total remaining performance obligations	$ 353
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 \| Gathering and Processing
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Total remaining performance obligations	$ 121
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Total remaining performance obligations	$ 367
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 \| Transportation and Storage
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Total remaining performance obligations	$ 266
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 \| Gathering and Processing
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Total remaining performance obligations	$ 101
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	22 years 5 months
Total remaining performance obligations	$ 1,172
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 \| Transportation and Storage
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	22 years 5 months
Total remaining performance obligations	$ 959
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 \| Gathering and Processing
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	4 years 2 months
Total remaining performance obligations	$ 213