Crestwood Equity Partners (CEQP) 10-K 25 Feb 22 2021 FY Annual report Financial data

Cover Page

Cover Page - USD ($)	12 Months Ended
	Dec. 31, 2021	Feb. 18, 2022	Jun. 30, 2021
Entity Information [Line Items]
Document Annual Report	true
Document Transition Report	false
Entity Registrant Name	Crestwood Equity Partners LP
Entity File Number	001-34664
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	43-1918951
Entity Address, Address Line One	811 Main Street
Entity Address, Address Line Two	Suite 3400
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	832
Local Phone Number	519-2200
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 1,700,000,000
Entity Common Stock, Shares Outstanding		97,978,074
Entity Central Index Key	0001136352
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
Amendment Flag	false
Documents Incorporated by Reference [Text Block]	DOCUMENTS INCORPORATED BY REFERENCE Portions of the following documents are incorporated by reference into the indicated parts of this report: Crestwood Equity Partners LP Portions of Crestwood Equity Partners LP’s Proxy Statement for the 2022 Annual Meeting of Stockholders are incorporated by reference into Items 10, 11, 12, 13 and 14 of Part III of this Form 10-K Crestwood Midstream Partners LP None Crestwood Midstream Partners LP, as a wholly-owned subsidiary of a reporting company, meets the conditions set forth in General Instruction (I)(1)(a) and (b) of Form 10-K and is therefore filing this report with the reduced disclosure format as permitted by such instruction.
ICFR Auditor Attestation Flag	true
Document Period End Date	Dec. 31, 2021
Current Fiscal Year End Date	--12-31
Document Type	10-K
CMLP
Entity Information [Line Items]
Entity Registrant Name	Crestwood Midstream Partners LP
Entity File Number	001-35377
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	20-1647837
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 0
Entity Common Stock, Shares Outstanding		0
Entity Central Index Key	0001304464
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
Amendment Flag	false
ICFR Auditor Attestation Flag	false
Document Period End Date	Dec. 31, 2021
Document Type	10-K
Common units
Entity Information [Line Items]
Title of 12(b) Security	Common Units representing limited partnership interests
Trading Symbol	CEQP
Security Exchange Name	NYSE
Preferred Units
Entity Information [Line Items]
Title of 12(b) Security	Preferred Units representing limited partner interests
Trading Symbol	CEQP-P
Security Exchange Name	NYSE

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2021
Auditor [Line Items]
Auditor Name	Ernst & Young LLP
Auditor Location	Houston, Texas
Auditor Firm ID	42
CMLP
Auditor [Line Items]
Auditor Name	Ernst & Young LLP
Auditor Location	Houston, Texas
Auditor Firm ID	42

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Assets
Cash	$ 13.3	$ 14
Accounts receivable, less allowance for doubtful accounts	378	262.2
Inventory	156.5	89.1
Assets from price risk management activities	42.1	27.2
Prepaid expenses and other current assets	14.8	13.4
Total current assets	604.7	405.9
Property, plant and equipment	3,771.5	3,759.6
Less: accumulated depreciation	992.1	842.5
Property, plant and equipment, net	2,779.4	2,917.1
Intangible assets	1,126.1	1,126.1
Less: accumulated amortization	393.2	331.8
Intangible assets, net	732.9	794.3
Goodwill	138.6	138.6
Operating lease right-of-use assets, net	27.4	36.8
Investments in unconsolidated affiliates	155.8	943.7
Other non-current assets	6.9	7.3
Total assets	4,445.7	5,243.7
Current liabilities:
Accounts payable	336.5	160.3
Accrued expenses and other liabilities	147.1	122
Liabilities from price risk management activities	114.6	76.3
Contingent consideration - current portion	0	19
Current portion of long-term debt	0.2	0.2
Total current liabilities	598.4	377.8
Long-term debt, less current portion	2,052.1	2,483.8
Contingent consideration	0	38
Other long-term liabilities	258.7	253.3
Deferred income taxes	2.3	2.7
Total liabilities	2,911.5	3,155.6
Commitments and contingencies (Note 10)
Interest of non-controlling partner in subsidiary	434.6	432.7
Interest of non-controlling partner in subsidiary
Partners' capital	487.6	1,043.4
Preferred units	612	612
Total partners’ capital	1,099.6	1,655.4
Total liabilities and capital	4,445.7	5,243.7
CMLP
Assets
Cash	12.9	13.7
Accounts receivable, less allowance for doubtful accounts	378	262.2
Inventory	156.5	89.1
Assets from price risk management activities	42.1	27.2
Prepaid expenses and other current assets	14.4	13.4
Total current assets	603.9	405.6
Property, plant and equipment	4,100.8	4,089.6
Less: accumulated depreciation	1,193	1,028.3
Property, plant and equipment, net	2,907.8	3,061.3
Intangible assets	1,126.1	1,126.1
Less: accumulated amortization	393.2	331.8
Intangible assets, net	732.9	794.3
Goodwill	138.6	138.6
Operating lease right-of-use assets, net	27.4	36.8
Investments in unconsolidated affiliates	155.8	943.7
Other non-current assets	4.8	5.2
Total assets	4,571.2	5,385.5
Current liabilities:
Accounts payable	336.4	157.8
Accrued expenses and other liabilities	146.1	120.1
Liabilities from price risk management activities	114.6	76.3
Contingent consideration - current portion	0	19
Current portion of long-term debt	0.2	0.2
Total current liabilities	597.3	373.4
Long-term debt, less current portion	2,052.1	2,483.8
Contingent consideration	0	38
Other long-term liabilities	254.1	251.8
Deferred income taxes	0.8	0.7
Total liabilities	2,904.3	3,147.7
Interest of non-controlling partner in subsidiary	434.6	432.7
Interest of non-controlling partner in subsidiary
Total CEQP/CMLP partners’ capital	1,232.3	1,805.1
Total liabilities and capital	$ 4,571.2	$ 5,385.5

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Allowance for doubtful accounts	$ 0.6	$ 0.9
Limited partners' units, issued	62,991,511	73,970,208
Limited partners' units, outstanding	62,991,511	73,970,208
Preferred units, outstanding (in units)	71,257,445	71,257,445
Preferred units, issued	71,257,445	71,257,445
CMLP
Allowance for doubtful accounts	$ 0.6	$ 0.9

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenues:
Revenues	$ 4,569	$ 2,254.3	$ 3,181.9
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 19)	136.8	21	45.4
Total costs of products/services sold	3,843.9	1,600.5	2,544.9
Operating expenses and other:
Operations and maintenance	121	131.8	138.8
General and administrative	97.6	91.5	103.4
Depreciation, amortization and accretion	244.2	237.4	195.8
Loss on long-lived assets, net	39.6	26	6.2
Goodwill impairment	0	0	(209.4)
Goodwill impairment	0	80.3	0
Total expenses	502.4	567	234.8
Operating income	222.7	86.8	402.2
Earnings (loss) from unconsolidated affiliates, net	(120.4)	32.5	32.8
Interest and debt expense, net	(132.1)	(133.6)	(115.4)
Gain (loss) on modification/extinguishment of debt	(7.5)	0.1	0
Other income (expense), net	0.1	(0.7)	0.6
Income (loss) before income taxes	(37.2)	(14.9)	320.2
Provision for income taxes	(0.2)	(0.4)	(0.3)
Net income (loss)	(37.4)	(15.3)	319.9
Net income attributable to non-controlling partner	41.1	40.8	34.8
Net income (loss) attributable to parent	(78.5)	(56.1)	285.1
Net income attributable to preferred units	60.1	60.1	60.1
Net income (loss) attributable to partners	$ (138.6)	$ (116.2)	$ 225
Net income (loss) per limited partner unit: (Note 14)
Basic (dollars per unit)	$ (2.11)	$ (1.59)	$ 3.11
Diluted (dollars per unit)	$ (2.11)	$ (1.59)	$ 2.93
Weighted-average limited partners’ units outstanding:
Basic (units)	65.6	73.2	71.8
Dilutive units (units)	0	0	5.1
Diluted (units)	65.6	73.2	76.9
CMLP
Revenues:
Revenues	$ 4,569	$ 2,254.3	$ 3,181.9
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 19)	136.8	21	45.4
Total costs of products/services sold	3,843.9	1,600.5	2,544.9
Operating expenses and other:
Operations and maintenance	121	131.8	138.8
General and administrative	90.2	86.7	98.2
Depreciation, amortization and accretion	258.4	251.5	209.9
Loss on long-lived assets, net	39.4	26	6.2
Goodwill impairment	0	0	(209.4)
Goodwill impairment	0	80.3	0
Total expenses	509	576.3	243.7
Operating income	216.1	77.5	393.3
Earnings (loss) from unconsolidated affiliates, net	(120.4)	32.5	32.8
Interest and debt expense, net	(132.1)	(133.6)	(115.4)
Gain (loss) on modification/extinguishment of debt	(7.5)	0.1	0
Other income (expense), net	0	0	0.2
Income (loss) before income taxes	(43.9)	(23.5)	310.9
Provision for income taxes	(0.1)	0.1	(0.3)
Net income (loss)	(44)	(23.4)	310.6
Net income attributable to non-controlling partner	41.1	40.8	34.8
Net income (loss) attributable to parent	(85.1)	(64.2)	275.8
Product
Revenues:
Revenues	4,145.4	1,793	2,752.4
Costs of product/services sold (exclusive of items shown separately below):
Product and service costs	3,688.8	1,558.8	2,469.7
Product | CMLP
Revenues:
Revenues	4,145.4	1,793	2,752.4
Costs of product/services sold (exclusive of items shown separately below):
Product and service costs	3,688.8	1,558.8	2,469.7
Product, Related Party
Revenues:
Revenues	25.8	27.3	2.9
Product, Related Party | CMLP
Revenues:
Revenues	25.8	27.3	2.9
Service
Revenues:
Revenues	396.4	433.5	426.6
Costs of product/services sold (exclusive of items shown separately below):
Product and service costs	18.3	20.7	29.8
Service | CMLP
Revenues:
Revenues	396.4	433.5	426.6
Costs of product/services sold (exclusive of items shown separately below):
Product and service costs	18.3	20.7	29.8
Service, Related Party
Revenues:
Revenues	1.4	0.5	0
Service, Related Party | CMLP
Revenues:
Revenues	$ 1.4	$ 0.5	$ 0

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ (37.4)	$ (15.3)	$ 319.9
Change in fair value of Suburban Propane Partners, L.P. units	0	0	0.3
Comprehensive income (loss)	(37.4)	(15.3)	320.2
Comprehensive income (loss) attributable to non-controlling partners	41.1	40.8	34.8
Comprehensive income (loss) attributable to Crestwood Equity Partners LP	$ (78.5)	$ (56.1)	$ 285.4

Consolidated Statement of Partn

Consolidated Statement of Partners' Capital - USD ($) $ in Millions	Total	CMLP	Preferred Units	Common Unit Capital	Common Unit CapitalCMLP	Limited Partners	Limited PartnersCMLP	Non-Controlling Partner	Non-Controlling PartnerCMLP	Total Partners’ Capital	Total Partners’ CapitalCMLP	Subordinated units	Common units	Preferred Units
Balance at the beginning of the period at Dec. 31, 2018			$ 612			$ 1,240.5	$ 2,028.2	$ 181.3	$ 181.3	$ 2,033.8	$ 2,209.5
Balance at the beginning of the period (in units) at Dec. 31, 2018												400,000	71,200,000
Preferred units balance at the beginning of the period (in units) at Dec. 31, 2018														71,300,000
Increase (Decrease) in Partners' Capital [Roll Forward]
Unit-based compensation charges						42.4	42.4			42.4	42.4
Unit-based compensation charges (in units)													1,000,000
Taxes paid for unit-based compensation vesting						(11)	(11)			(11)	(11)
Taxes paid for unit-based compensation vesting (in units)													(300,000)
Distributions to partners			(60.1)			(172.4)	(235.8)	(6.6)	(6.6)	(239.1)	(242.4)
Change in fair value of Suburban Propane Partners, L.P. units						0.3				0.3
Non-controlling interest reclassification (Note 12)	$ 178.8							(178.8)	(178.8)	(178.8)	(178.8)
Other				$ (4)	$ (0.3)			0.1	0.1	(3.9)	(0.2)
Net income (loss)	319.9	$ 310.6	60.1			225	275.8	4	4	289.1	279.8
Balance at the beginning of the period (in units) at Dec. 31, 2019												400,000	71,900,000
Preferred units balance at the end of the period (in units) at Dec. 31, 2019														71,300,000
Balance at the end of the period at Dec. 31, 2019			612			1,320.8	2,099.3	0	0	1,932.8	2,099.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Unit-based compensation charges						34	29.3			34	29.3
Unit-based compensation charges (in units)													2,100,000
Taxes paid for unit-based compensation vesting						(15.6)	(15.6)			(15.6)	(15.6)
Taxes paid for unit-based compensation vesting (in units)													(600,000)
Stockholders' Equity, Other Shares													200,000
Distributions to partners			(60.1)			(182.7)	(242.6)			(242.8)	(242.6)
Other				3.1	(1.1)					3.1	(1.1)
Net income (loss)	$ (15.3)	(23.4)	60.1			(116.2)	(64.2)			(56.1)	(64.2)
Balance at the beginning of the period (in units) at Dec. 31, 2020												400,000	73,600,000
Preferred units balance at the end of the period (in units) at Dec. 31, 2020	71,257,445													71,300,000
Balance at the end of the period at Dec. 31, 2020		1,805.1	612			1,043.4	1,805.1	0	0	1,655.4	1,805.1
Increase (Decrease) in Partners' Capital [Roll Forward]
Total partners’ capital	$ 1,655.4
Contingent consideration - current portion	19	19
Crestwood Holdings Transactions (Note 12)				(273.2)						(273.2)
Unit-based compensation charges						32	30.5			32	30.5
Unit-based compensation charges (in units)													1,300,000
Taxes paid for unit-based compensation vesting						(8.4)	(8.4)			(8.4)	(8.4)
Taxes paid for unit-based compensation vesting (in units)													(400,000)
Retirement of units (Note 12)												(400,000)	(11,500,000)
Distributions to partners			(60.1)			(164.3)	(509.7)			(224.4)	(509.7)
Other				$ (3.3)	$ (0.1)					(3.3)	(0.1)
Net income (loss)	$ (37.4)	(44)	60.1			(138.6)	(85.1)			(78.5)	(85.1)
Balance at the beginning of the period (in units) at Dec. 31, 2021												0	63,000,000
Preferred units balance at the end of the period (in units) at Dec. 31, 2021	71,257,445													71,300,000
Balance at the end of the period at Dec. 31, 2021		1,232.3	$ 612			$ 487.6	$ 1,232.3	$ 0	$ 0	$ 1,099.6	$ 1,232.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Total partners’ capital	$ 1,099.6
Contingent consideration - current portion	$ 0	$ 0

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating activities
Net income (loss)	$ (37.4)	$ (15.3)	$ 319.9
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	244.2	237.4	195.8
Amortization of debt-related deferred costs	6.7	6.5	6.2
Unit-based compensation charges	34.9	30.7	47
Loss on long-lived assets, net	39.6	26	6.2
Goodwill impairment	0	0	(209.4)
Goodwill impairment	0	80.3	0
(Gain) loss on modification/extinguishment of debt	7.5	(0.1)	0
(Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received	138	6.5	6.9
Deferred income taxes	(0.4)	0.1	0
Other	0.3	(0.1)	0
Changes in operating assets and liabilities:
Accounts receivable	(114.3)	(27.5)	42.9
Inventory	(67.4)	(33.7)	10.9
Prepaid expenses and other current assets	(1)	(3.7)	0.1
Accounts payable, accrued expenses and other liabilities	148.3	(1.2)	(23.3)
Reimbursements of property, plant and equipment	4.3	15.7	24.8
Increase (Decrease) in Derivative Assets and Liabilities	23.4	86.5	(7.6)
Net cash provided by operating activities	426.7	408.1	420.4
Investing activities
Acquisitions, net of cash acquired (Note 3)	0	(162.3)	(462.1)
Purchases of property, plant and equipment	(83.2)	(168.3)	(455.5)
Investments in unconsolidated affiliates	(17.6)	(9.4)	(61.3)
Capital distributions from unconsolidated affiliates	652	39.4	35.5
Net proceeds from sale of long-lived assets, including equity investments	17.7	27.3	0.8
Other	0	0	(1.1)
Net cash provided by (used in) investing activities	568.9	(273.3)	(943.7)
Financing activities
Proceeds from the issuance of long-term debt	2,859.5	1,125.1	2,307.3
Payments on long-term debt	(3,287.5)	(975.8)	(1,729.5)
Payments on finance leases	2.8	3.1	3.5
Payments for deferred financing costs	(17.9)	0	(9)
Net proceeds from issuance of non-controlling interest	1	2.8	235
Payments for Crestwood Holdings Transactions	(275.6)	0	0
Distributions to partners	(164.3)	(182.7)	(172.4)
Distributions to non-controlling partner	(40.2)	(37.1)	(25)
Distributions to preferred unitholders	(60.1)	(60.1)	(60.1)
Taxes paid for unit-based compensation vesting	(8.4)	(15.6)	(11)
Net cash provided by (used in) financing activities	(996.3)	(146.5)	531.8
Net change in cash and restricted cash	(0.7)	(11.7)	8.5
Cash and restricted cash at beginning of period	14	25.7	17.2
Cash and restricted cash at end of period	13.3	14	25.7
Supplemental disclosure of cash flow information
Cash paid for interest	125.9	129.8	123.7
Cash paid for income taxes	0.8	0.6	0.6
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	(5.8)	40	(27.7)
CMLP
Operating activities
Net income (loss)	(44)	(23.4)	310.6
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	258.4	251.5	209.9
Amortization of debt-related deferred costs	6.7	6.5	6.2
Unit-based compensation charges	34.9	30.7	47
Loss on long-lived assets, net	39.4	26	6.2
Goodwill impairment	0	0	(209.4)
Goodwill impairment	0	80.3	0
(Gain) loss on modification/extinguishment of debt	7.5	(0.1)	0
(Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received	138	6.5	6.9
Deferred income taxes	0	0	0.2
Other	0.3	(0.1)	0
Changes in operating assets and liabilities:
Accounts receivable	(114.3)	(27.8)	41.6
Inventory	(67.4)	(33.7)	10.9
Prepaid expenses and other current assets	(0.6)	(4.6)	0.1
Accounts payable, accrued expenses and other liabilities	147.8	(6.1)	(23.3)
Reimbursements of property, plant and equipment	4.3	15.7	24.8
Increase (Decrease) in Derivative Assets and Liabilities	23.4	86.5	(7.6)
Net cash provided by operating activities	434.4	407.9	424.1
Investing activities
Acquisitions, net of cash acquired (Note 3)	0	(162.3)	(462.1)
Purchases of property, plant and equipment	(81.3)	(168.3)	(455.5)
Investments in unconsolidated affiliates	(17.6)	(9.4)	(61.3)
Capital distributions from unconsolidated affiliates	652	39.4	35.5
Net proceeds from sale of long-lived assets, including equity investments	17.7	27.3	0.8
Other	0	0	(1.1)
Net cash provided by (used in) investing activities	570.8	(273.3)	(943.7)
Financing activities
Proceeds from the issuance of long-term debt	2,859.5	1,125.1	2,307.3
Payments on long-term debt	(3,287.5)	(975.8)	(1,729.5)
Payments on finance leases	2.8	3.1	3.5
Payments for deferred financing costs	(17.9)	0	(9)
Net proceeds from issuance of non-controlling interest	1	2.8	235
Distributions to partners	(509.7)	(242.6)	(235.8)
Distributions to non-controlling partner	(40.2)	(37.1)	(25)
Taxes paid for unit-based compensation vesting	(8.4)	(15.6)	(11)
Net cash provided by (used in) financing activities	(1,006)	(146.3)	528.5
Net change in cash and restricted cash	(0.8)	(11.7)	8.9
Cash and restricted cash at beginning of period	13.7	25.4	16.5
Cash and restricted cash at end of period	12.9	13.7	25.4
Supplemental disclosure of cash flow information
Cash paid for interest	125.9	129.8	123.7
Cash paid for income taxes	0.5	0.5	0.6
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$ (5.8)	$ 40	$ (27.7)

Organization and Description of

Organization and Description of Business	12 Months Ended
	Dec. 31, 2021
Disclosure Partnership Organization And Basis Of Presentation Narrative [Abstract]
Organization and Description of Business	Organization and Description of Business The accompanying notes to the consolidated financial statements apply to Crestwood Equity Partners LP (the Company, Crestwood Equity or CEQP) and Crestwood Midstream Partners LP (Crestwood Midstream or CMLP) unless otherwise indicated. Organization Crestwood Equity Partners LP . CEQP is a publicly-traded (NYSE: CEQP) Delaware limited partnership formed in March 2001. Crestwood Equity GP LLC (Crestwood Equity GP), our wholly-owned subsidiary, owns our non-economic general partnership interest. Prior to the Crestwood Holdings Transactions described below, Crestwood Equity was indirectly owned by Crestwood Holdings LLC (Crestwood Holdings), which was substantially owned and controlled by First Reserve Management, L.P. (First Reserve). Crestwood Midstream Partners LP . Crestwood Equity owns a 99.9% limited partnership interest in Crestwood Midstream and Crestwood Gas Services GP LLC (CGS GP), a wholly-owned subsidiary of Crestwood Equity, owns a 0.1% limited partnership interest in Crestwood Midstream. Crestwood Midstream GP LLC, a wholly-owned subsidiary of Crestwood Equity, owns the non-economic general partnership interest of Crestwood Midstream. Crestwood Holdings Transactions. In March 2021, CEQP paid Crestwood Holdings approximately $268 million to (i) acquire approximately 11.5 million CEQP common units, 0.4 million subordinated units of CEQP and 100% of the equity interests of Crestwood Marcellus Holdings LLC and Crestwood Gas Services Holdings LLC (whose assets consisted solely of CEQP common and subordinated units and 1% of the limited partner interests in Crestwood Holdings LP) in March 2021; and (ii) acquire the general partner and the remaining 99% limited partner interests of Crestwood Holdings LP (whose assets consist solely of its ownership interest in Crestwood Equity GP, which owns CEQP’s non-economic general partner interest) in August 2021 (collectively, the Crestwood Holdings Transactions). The purchase price was funded through borrowings under the Crestwood Midstream credit facility. CEQP retired the common and subordinated units acquired in the Crestwood Holdings Transactions. Unless otherwise indicated, references in this report to “we,” “us,” “our,” “ours,” “our company,” the “partnership,” the “Company,” “Crestwood Equity,” “CEQP,” and similar terms refer to either Crestwood Equity Partners LP itself or Crestwood Equity Partners LP and its consolidated subsidiaries, as the context requires. Unless otherwise indicated, references to “Crestwood Midstream” and “CMLP” refer to Crestwood Midstream Partners LP and its consolidated subsidiaries. Description of Business Crestwood Equity develops, acquires, owns or controls, and operates primarily fee-based assets and operations within the energy midstream sector. We provide broad-ranging infrastructure solutions across the value chain to service premier liquids-rich natural gas and crude oil shale plays across the United States. We own and operate a diversified portfolio of NGL, crude oil, natural gas and produced water gathering, processing, storage, disposal and transportation assets that connect fundamental energy supply with energy demand across the United States. Crestwood Equity is a holding company and all of its consolidated operating assets are owned by or through its wholly-owned subsidiary, Crestwood Midstream.

Basis of Presentation and Summa

Basis of Presentation and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Basis of Presentation and Summary of Significant Accounting Policies	Basis of Presentation and Summary of Significant Accounting Policies Basis of Presentation Our consolidated financial statements are prepared in accordance with GAAP and include the accounts of all consolidated subsidiaries after the elimination of all intercompany accounts and transactions. Certain amounts in prior periods have been reclassified to conform to the current year presentation, none of which impacted our previously reported net income, earnings per unit or partners’ capital. In management’s opinion, all necessary adjustments to fairly present our results of operations, financial position and cash flows for the periods presented have been made and all such adjustments are of a normal and recurring nature. Significant Accounting Policies Principles of Consolidation We consolidate entities when we have the ability to control or direct the operating and financial decisions of the entity or when we have a significant interest in the entity that gives us the ability to direct the activities that are significant to that entity. The determination to consolidate or apply the equity method of accounting to an entity can also require us to evaluate whether that entity is considered a variable interest entity. This evaluation, along with the determination of our ability to control, direct or exert significant influence over an entity involves the use of judgment. We apply the equity method of accounting where we can exert significant influence over, but do not control or direct the policies, decisions or activities of an entity. We use the cost method of accounting where we are unable to exert significant influence over the entity. Use of Estimates The preparation of our consolidated financial statements in conformity with GAAP requires the use of estimates and assumptions that affect the amounts we report as assets, liabilities, revenues and expenses and our disclosures in these consolidated financial statements. Actual results can differ from those estimates. Cash We consider all highly liquid investments with an original maturity of less than three months to be cash. Accounts Receivable On January 1, 2020, we adopted the provisions of ASU 2016-13, Financial Instruments - Credit Losses (Topic 326) , which provides revised guidance on evaluating accounts and notes receivable and other financial instruments for impairment. We record accounts receivable when products or services are delivered and it is probable that payment will be received for those products or services, and we do not record any interest or penalties on accounts receivable that are past due under the terms of the related arrangement or invoice until those amounts are received. Topic 326 requires companies to evaluate their financial instruments for impairment by recording an allowance for doubtful accounts and/or bad debt expense based on certain categories of instruments rather than a specific identification approach. We adopted the provisions of this standard using a method to estimate the allowance for doubtful accounts that considered both the aging of our accounts receivable and the projected loss rate of our receivables. We write off accounts receivable, and the related allowance for doubtful accounts, when it becomes remote that payment for products or services will be received. On January 1, 2020, we recorded a $0.7 million increase to our allowance for doubtful accounts and a $0.7 million decrease to partners’ capital to reflect the cumulative effect of adopting the new standard. In addition, on January 1, 2020, Crestwood Permian Basin Holdings LLC (Crestwood Permian), our 50% equity investment, also adopted the provisions of Topic 326 and we recorded a decrease of approximately $0.2 million to our equity investment and a corresponding decrease to our partners’ capital to reflect our proportionate share of the cumulative effect of accounting change recorded by the equity investment related to the new standard. The adoption of this standard was not material to our other equity investments. Inventory Our inventory, which is stated at the lower of cost or net realizable value and cost is computed predominantly using the average cost method, consisted of the following ( in millions ): December 31, 2021 2020 NGLs, crude oil and natural gas $ 155.6 $ 88.0 Spare parts 0.9 1.1 Total inventory $ 156.5 $ 89.1 Property, Plant and Equipment Property, plant and equipment is recorded at is original cost of construction or, upon acquisition, at the fair value of the assets acquired. For assets we construct, we capitalize direct costs, such as labor and materials, and indirect costs, such as overhead and interest. We capitalize major units of property replacements or improvement and expense minor items. Depreciation is computed using the straight-line method over the estimated useful lives of the assets, as follows: Years Gathering systems and pipelines 15 - 20 Facilities and equipment 3 - 25 Buildings, rights-of-way and easements 1 - 40 Office furniture and fixtures 5- 10 Vehicles 5 We evaluate our long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If such events or changes in circumstances are present, a loss is recognized if the carrying value of the asset is in excess of the sum of the undiscounted cash flows expected to result from the use of the asset and its eventual disposition. An impairment loss is measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset, which is typically based on discounted cash flow projections using assumptions as to revenues, costs and discount rates typical of third party market participants, which is a Level 3 fair value measurement. Projected cash flows of our property, plant and equipment are generally based on current and anticipated future market conditions, which require significant judgment to make projections and assumptions about pricing, demand, competition, operating costs, constructions costs, legal and regulatory issues and other factors that may extend many years into the future and are often outside of our control. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. During 2021, we recorded $40.1 million of impairments of our property, plant and equipment to reflect our gathering and processing south segment’s compressor stations in our western Marcellus operations at fair value based on the actual or anticipated dismantlement and redeployment of those assets to other areas. At December 31, 2021, our estimates of fair value considered a number of factors, including the potential value we would receive if we sold the asset and projected cash flows discounted at a 12% discount rate, which are Level 3 fair value measurements. During 2020 and 2019, we recorded $3.1 million and $4.3 million of impairments of our property, plant and equipment primarily related to the removal and retirement of certain water gathering facilities in response to several produced water releases on our Arrow system over the past few years, which is further discussed in Note 10. During 2020, we sold our Fayetteville assets and recorded a loss on long-lived assets of approximately $19.9 million (see Note 3 for a further discussion of the assets sale). Identifiable Intangible Assets Our identifiable intangible assets consist of customer accounts, trademarks and certain revenue contracts. These intangible assets have arisen primarily from acquisitions. We amortize certain of our revenue contracts based on the projected cash flows associated with these contracts if the projected cash flows are readily determinable, otherwise we amortize our revenue contracts on a straight-line basis. We recognize acquired intangible assets separately if the benefit of the intangible asset is obtained through contractual or other legal rights, or if the intangible asset can be sold, transferred, licensed, rented or exchanged, regardless of the acquirer’s intent to do so. Projected cash flows of our intangible assets are generally based on current and anticipated future market conditions, which require significant judgment to make projections and assumptions about pricing, demand, competition, operating costs, construction costs, legal and regulatory issues and other factors that may extend many years into the future and are often outside of our control. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. We did not record any impairments of our intangible assets during the years ended December 31, 2021, 2020 or 2019. Certain intangible assets are amortized on a straight-line basis over their estimated economic lives, as follows: Weighted-Average Life (years) Customer accounts 22 Revenue contracts 18 Trademarks 10 Goodwill Our goodwill represents the excess of the amount we paid for a business over the fair value of the net identifiable assets acquired. We evaluate goodwill for impairment annually on December 31, and whenever events indicate that it is more likely than not that the fair value of a reporting unit could be less than its carrying amount. This evaluation requires us to compare the fair value of each of our reporting units to its carrying value (including goodwill). If the fair value exceeds the carrying amount, goodwill of the reporting unit is not considered impaired. We estimate the fair value of our reporting units based on a number of factors, including discount rates, projected cash flows and the potential value we would receive if we sold the reporting unit. Estimating projected cash flows requires us to make certain assumptions as it relates to the future operating performance of each of our reporting units (which includes assumptions, among others, about estimating future operating margins and related future growth in those margins, contracting efforts and the cost and timing of facility expansions) and assumptions related to our customers, such as their future capital and operating plans and their financial condition. When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. If the assumptions embodied in the projections prove inaccurate, we could incur a future impairment charge. In addition, the use of the income approach to determine the fair value of our reporting units (see further discussion of the use of the income approach below) could result in a different fair value if we had utilized a market approach, or a combination thereof. Upon acquisition, we are required to record the assets, liabilities and goodwill of a reporting unit at its fair value on the date of acquisition. As a result, any level of decrease in the forecasted cash flows of these businesses or increases in the discount rates utilized to value those businesses from their respective acquisition dates would likely result in the fair value of the reporting unit falling below the carrying value of the reporting unit, and could result in an assessment of whether that reporting unit’s goodwill is impaired. We acquired our Powder River Basin reporting unit in 2019 and recorded it at fair value at that time. During 2020, current and forward commodity prices significantly declined from their levels at December 31, 2019 due primarily to the decreases in energy demand as a result of the outbreak of the COVID-19 pandemic and actions taken by the Organization of the Petroleum Exporting Countries, Russia, the United States and other oil-producing countries relating to the oversupply of oil. Based on these events, we determined that the forecasted cash flows, and therefore the fair value, of our Powder River Basin reporting unit significantly decreased during 2020, and accordingly performed a quantitative impairment assessment of the goodwill related to that reporting unit during that period. Based on our quantitative assessment, which utilized the income approach, we determined that the goodwill associated with the Powder River Basin reporting unit should be fully impaired, and accordingly we recorded an $80.3 million impairment of the goodwill attributed to that reporting unit during the year ended December 31, 2020. The following table summarizes the goodwill of our reporting units ( in millions ). We did not record any impairments of the goodwill associated with our Arrow or NGL Marketing and Logistics reporting units during the years ended December 31, 2021, 2020 and 2019. At December 31, 2021, our accumulated goodwill impairments at CEQP and CMLP were approximately $1,736.8 million and $1,479.6 million, respectively. Goodwill at January 1, 2020 Impairment during the Year Ended December 31, 2020 Goodwill at December 31, 2020 Goodwill at December 31, 2021 Gathering and Processing North Arrow $ 45.9 $ — $ 45.9 $ 45.9 Powder River Basin 80.3 (80.3) — — Storage and Logistics NGL Marketing and Logistics 92.7 — 92.7 92.7 Total $ 218.9 $ (80.3) $ 138.6 $ 138.6 Leases We enter into leases with third parties for the right to utilize certain office buildings, crude oil railroad cars, vehicles and other operating facilities and equipment. For contracts that extend for a period greater than 12 months, we recognize a right-of-use asset and a corresponding lease liability on our consolidated balance sheet based on the present value of each lease, which is based on the future minimum lease payments and is determined by discounting these payments using our incremental borrowing rate. We recognize operating lease expense on our consolidated statements of operations as either costs of product/services sold, operations and maintenance expenses or general and administrative expenses on a straight-line basis over the lease term. We do not have any material leases where we are considered to be the lessor. Our lease agreements do not contain any material residual value guarantees or material restrictive covenants. We do not have any material revenue contracts that are considered leases. Investments in Unconsolidated Affiliates Equity method investments in which we exercise significant influence, but do not control and are not the primary beneficiary, are accounted for using the equity method of accounting. Differences in the basis of investments and the separate net asset values of the investees, if any, are amortized into net income or loss over the remaining useful lives of the underlying assets and liabilities, except for the excess related to goodwill. We evaluate our equity method investments for impairment when events or circumstances indicate that the carrying value of the equity method investment may be impaired and that impairment is other than temporary. If an event occurs, we evaluate the recoverability of our carrying value based on the fair value of the investment. If an impairment is indicated, or if we decide to sell an investment in an unconsolidated affiliate, we adjust the carrying values of the asset downward, if necessary, to their estimated fair values. We did not record impairments of our equity method investments during the years ended December 31, 2021, 2020 and 2019. See Note 6 for a discussion of the impairments recorded by our Stagecoach Gas equity method investment related to the sale of its assets, including our proportionate share of the losses which we recorded as a reduction to our earnings from unconsolidated affiliates during the year ended December 31, 2021. Asset Retirement Obligations An asset retirement obligation (ARO) is an estimated liability for the cost to retire a tangible asset. We record a liability for legal or contractual obligations to retire our long-lived assets associated with our facilities and right-of-way contracts we hold. We record a liability in the period the obligation is incurred and estimable. An ARO is initially recorded at its estimated fair value with a corresponding increase to property, plant and equipment. This increase in property, plant and equipment is then depreciated over the useful life of the asset to which that liability relates. An ongoing expense is recognized for changes in the fair value of the liability as a result of the passage of time, which we record as depreciation, amortization and accretion expense on our consolidated statements of operations. We have various obligations to remove property, plant and equipment on rights-of-way and leases for which we cannot currently estimate the fair value of those obligations because the associated assets have indeterminate lives. An asset retirement obligation liability (and related assets), if any, will be recorded for these obligations once sufficient information is available to reasonably estimate the fair value of the obligations. Our current AROs are reflected in accrued expenses and other liabilities and our long-term AROs are reflected in other long-term liabilities on our consolidated balance sheets. Deferred Financing Costs Deferred financing costs represent costs associated with obtaining long-term financing and are amortized over the term of the related debt using a method which approximates the effective interest method and has a weighted average remaining life of six years. Our net deferred financing costs are reflected as a reduction of long-term debt on our consolidated balance sheets. Environmental Costs and Other Contingencies We recognize liabilities for environmental and other contingencies when there is an exposure that indicates it is both probable that a liability has been incurred and the amount of loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue a liability for that amount. Where the most likely outcome cannot be estimated, a range of potential losses is established and if no one amount in that range is more likely than any other, the low end of the range is accrued. We record liabilities for environmental contingencies at their undiscounted amounts on our consolidated balance sheets as accrued expenses and other liabilities when environmental assessments indicate that remediation efforts are probable and costs can be reasonably estimated. Estimates of our liabilities are based on currently available facts and presently enacted laws and regulations, taking into consideration the likely effects of other societal and economic factors. These estimates are subject to revision in future periods based on actual costs or new circumstances. We capitalize costs that benefit future periods and recognize a current period charge in operations and maintenance expenses when clean-up efforts do not benefit future periods. We evaluate potential recoveries of amounts from third parties, including insurance coverage, separately from our liability. Recovery is evaluated based on the solvency of the third party, among other factors. When recovery is assured, we record and report an asset separately from the associated liability on our consolidated balance sheet. Revenue Recognition We provide gathering, processing, compression, storage, fractionation, and transportation (consisting of pipelines, truck and rail terminals, truck/trailer units and rail cars) services and we sell commodities (including crude oil, natural gas and NGLs) under various contracts, which are described below. • Fixed-fee contracts . Under these contracts, we do not take title to the underlying crude oil, natural gas, NGLs and water but charge our customers a fixed-fee for the services we provide, which can be a firm reservation charge and/or a charge per volume gathered, processed, compressed, stored, loaded and/or transported (which, in certain contracts, can be subject to a minimum level of volumes). • Percentage-of-proceeds service contracts . Under these contracts, we take title to crude oil, natural gas or NGLs after the commodity leaves our gathering and processing facilities. We often market and sell those commodities to third parties after they leave our facilities and we will remit a portion of the sales proceeds to our producers. • Percentage-of-proceeds product contracts. Under these contracts, we take title to crude oil, natural gas or NGLs before the commodity enters our facilities. We market and sell those commodities to third parties and we will remit a portion of the sales proceeds to our producers. • Purchase and sale contracts . Under these contracts, we purchase crude oil, natural gas or NGLs before the commodity enters our facilities, and we market and sell those commodities to third parties. We recognize revenues for services and products under revenue contracts as our obligations to perform services or deliver/sell products under the contracts are satisfied. A contract’s transaction price is allocated to each performance obligation in the contract and recognized as revenue when, or as, the performance obligation is satisfied. Our fixed-fee contracts and our percentage-of-proceeds service contracts primarily have a single performance obligation to deliver a series of distinct goods or services that are substantially the same and have the same pattern of transfer to our customers. For performance obligations associated with these contracts, we recognize revenues over time utilizing the output method based on the actual volumes of products delivered/sold or services performed, because the single performance obligation is satisfied over time using the same performance measure of progress toward satisfaction of the performance obligation . The transaction price under certain of our fixed-fee contracts and percentage-of-proceeds service contracts includes variable consideration that varies primarily based on actual volumes that are delivered under the contracts. Because the variable consideration specifically relates to our efforts to transfer the services and/or products under the contracts, we allocate the variable consideration entirely to the distinct service, and accordingly recognize the variable consideration as revenues at the time the good or service is transferred to the customer. Certain of our fixed-fee contracts contain minimum volume features under which the customers must utilize our services to gather, compress or load a specified quantity of crude oil or natural gas or pay a deficiency fee based on the difference between actual volumes and the contractual minimum volume. We recognize revenues from these contracts when actual volumes are gathered, compressed or loaded and the likelihood of a customer exercising its remaining rights to make up the deficient volumes under minimum volume commitments becomes remote. We recognize revenues at a point in time for performance obligations associated with our percentage-of proceeds product contracts and purchase and sale contracts, and these revenues are recognized because control of the underlying product is transferred to the customer when the distinct good is provided to the customer. The evaluation of when performance obligations have been satisfied and the transaction price that is allocated to our performance obligations requires significant judgments and assumptions, including our evaluation of the timing of when control of the underlying good or service has transferred to our customers and the relative standalone selling price of goods and services provided to customers under contracts with multiple performance obligations. Actual results can significantly vary from those judgments and assumptions. We did not have any material contracts with multiple performance obligations or under which we receive material amounts of non-cash consideration during the year ended December 31, 2021. Amounts due from our customers under our revenue contracts are typically billed as the service is being provided or on a weekly, bi-weekly or monthly basis and are due within 30 days of billing. Under certain of our contracts, we recognize revenues in excess of billings which we present as contract assets on our consolidated balance sheets. Under certain contracts, we are entitled to receive payments in advance of satisfying our performance obligations under the contracts. We recognize a liability for these payments in excess of revenue recognized and present it as deferred revenue or contract liabilities on our consolidated balance sheets. Our deferred revenue primarily relates to: • Capital Reimbursements. Certain of our contracts require that our customers reimburse us for capital expenditures related to the construction of long-lived assets utilized to provide services to them under the respective revenue contracts. Because we consider these amounts as consideration from customers associated with ongoing services to be provided to customers, we defer these upfront payments in deferred revenue and recognize the amounts in revenue over the life of the associated revenue contract as the performance obligations are satisfied under the contract. • Contracts with Increasing (Decreasing) Rates per Unit. Certain of our contracts have fixed rates per volume that increase and/or decrease over the life of the contract once certain time periods or thresholds are met. We record revenues on these contracts ratably per unit over the life of the contract based on the remaining performance obligations to be performed, which can result in the deferral of revenue for the difference between the consideration received and the ratable revenue recognized. Credit Risk and Concentrations Inherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. Income Taxes Crestwood Equity is a master limited partnership and Crestwood Midstream is a limited partnership. Partnerships are generally not subject to federal income tax, although publicly-traded partnerships are treated as corporations for federal income tax purposes and therefore are subject to federal income tax, unless the partnership generates at least 90% of its gross income from qualifying sources. If the qualifying income requirement is satisfied, the publicly-traded partnership will be treated as a partnership for federal income tax purposes. We satisfy the qualifying income requirement and are treated as a partnership for federal and state income tax purposes. Our consolidated earnings are included in the federal and state income tax returns of our partners. However, legislation in certain states allows for taxation of partnerships, and as such, certain state taxes have been included in our accompanying financial statements as income taxes due to the nature of the tax in those particular states as discussed below. In addition, federal and state income taxes are provided on the earnings of the subsidiaries incorporated as taxable entities. We are required to recognize deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements or tax returns. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial reporting and tax basis of assets and liabilities using expected rates in effect for the year in which the differences are expected to reverse. We are responsible for the Texas Margin tax included in our Texas franchise tax returns. The margin tax qualifies as an income tax under GAAP, which requires us to recognize the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis attributable to such tax. Net earnings for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax basis and the financial reporting basis of assets and liabilities and the taxable income allocation requirements under the partnership agreement. Price Risk Management Activities We utilize certain derivative financial instruments to (i) manage our exposure to commodity price risk, specifically, the related change in the fair value of inventory, as well as the variability of cash flows related to forecasted transactions; and (ii) ensure the availability of adequate physical supply of commodity. We record all derivative instruments as either assets or liabilities on our consolidated balance sheets at their fair values. Changes in the fair value of these derivative financial instruments are recorded through current earnings. We do not have any derivatives designated as fair value hedges or cash flow hedges for accounting purposes. Unit-Based Compensation

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2021
Business Combination and Asset Acquisition [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestiture Acquisitions NGL Asset Acquisition In April 2020, we acquired several NGL storage and rail-to-truck terminals from Plains All American Pipeline, L.P. for approximately $162 million (NGL Asset Acquisition). The acquired assets include 7 MMBbls of NGL storage and seven terminals, and resulted in an increase of approximately $110 million to our property, plant and equipment, $50 million to our intangible assets and $2 million to our other assets and liabilities, net. The identifiable intangible assets primarily consist of customer accounts with a weighted-average remaining life of 20 years on the date of acquisition. We allocated the purchase price to these assets and liabilities based on their fair values, which are Level 3 fair value measurements and were developed by management with the assistance of a third-party valuation firm utilizing market-related information about the property, plant and equipment and customer relationships acquired. These assets are included in our storage and logistics segment. The transaction costs related to this acquisition were not material during the year ended December 31, 2020. Jackalope Acquisition On April 9, 2019, Crestwood Niobrara LLC (Crestwood Niobrara), our consolidated subsidiary, acquired Williams Partners LP’s (Williams) 50% equity interest in Jackalope Gas Gathering Services, L.L.C. (Jackalope) for approximately $484.6 million (Jackalope Acquisition). The acquisition was funded through a combination of borrowings under the CMLP credit facility and the issuance of $235 million of new preferred units to CN Jackalope Holdings LLC (Jackalope Holdings) (see Note 12 for a further discussion of the issuance of the new preferred units). Prior to the Jackalope Acquisition, Crestwood Niobrara owned a 50% equity interest in Jackalope, which we accounted for under the equity method of accounting. As a result of this transaction, Crestwood Niobrara controls and owns 100% of the equity interests in Jackalope. The financial results of Jackalope are included in our gathering and processing north segment. Transaction costs related to the Jackalope Acquisition were approximately $2.8 million during the year ended December 31, 2019. These costs are included in operations and maintenance expenses in our consolidated statements of operations. The fair values of the assets acquired and liabilities assumed were determined primarily utilizing market-related information and other projections on the anticipated performance of the assets acquired, including an analysis of the future discounted cash flows to be generated by the acquired assets at a discount rate of approximately 12%. Those fair values are Level 3 fair value measurements and were developed by management with the assistance of a third-party valuation firm. The following table summarizes the final valuation of the assets acquired and liabilities assumed at the acquisition date (in millions ): Cash $ 22.5 Other current assets 30.9 Property, plant and equipment 532.9 Intangible assets 306.0 Goodwill 80.3 Current liabilities (30.4) Other long-term liabilities (21.5) Estimated fair value of 100% interest in Jackalope 920.7 Less: Elimination of equity investment in Jackalope 226.7 Gain on acquisition of Jackalope 209.4 Total purchase price $ 484.6 The identifiable intangible assets primarily consists of a customer contract with a weighted-average remaining life of 17 years on the date of acquisition. The goodwill recognized related primarily to anticipated operating synergies between the assets acquired and our existing operations. The fair value of the assets acquired and liabilities assumed in the Jackalope Acquisition exceeded the sum of the cash consideration paid and the historical book value of our 50% equity interest in Jackalope (which was remeasured at fair value and derecognized) and, as a result, we recognized a gain of approximately $209.4 million during the year ended December 31, 2019. This gain is included in gain on acquisition in our consolidated statements of operations. Our consolidated statements of operations include the results of Jackalope in our gathering and processing north segment since April 9, 2019, the closing date of the acquisition. During the year ended December 31, 2019, we recognized approximately $70.1 million of revenues and $20.9 million of net income related to Jackalope’s operations. The tables below present selected unaudited pro forma information as if the Jackalope Acquisition had occurred on January 1, 2019 (in millions) . The pro forma information is not necessarily indicative of the financial results that would have occurred if the transaction had been completed as of the date indicated. The amounts were calculated after applying our accounting policies and adjusting the results to reflect the depreciation, amortization and accretion expense that would have been charged assuming the fair value adjustments to property, plant and equipment and intangible assets had been made at the beginning of the reporting period. The pro forma net income also includes the effects of interest expense on incremental borrowings and recognition of deferred revenue. Crestwood Equity Year Ended December 31, 2019 Revenues $ 3,202.6 Net income $ 313.5 Crestwood Midstream Year Ended December 31, 2019 Revenues $ 3,202.6 Net income $ 304.2

Certain Balance Sheet Informati

Certain Balance Sheet Information	12 Months Ended
	Dec. 31, 2021
Balance Sheet Related Disclosures [Abstract]
Certain Balance Sheet Information	Certain Balance Sheet Information Property, Plant and Equipment Property, plant and equipment consisted of the following ( in millions ): CEQP CMLP December 31, December 31, 2021 2020 2021 2020 Gathering systems and pipelines and related assets $ 1,052.5 $ 1,035.2 $ 1,195.2 $ 1,178.0 Facilities and equipment 2,200.6 2,193.5 2,385.8 2,378.6 Buildings, land, rights-of-way, storage rights and easements 391.8 389.0 395.5 392.7 Vehicles 17.0 13.9 14.5 12.1 Construction in process 64.7 83.6 64.7 83.6 Finance leases 12.3 13.3 12.3 13.3 Office furniture and fixtures 32.6 31.1 32.8 31.3 3,771.5 3,759.6 4,100.8 4,089.6 Less: accumulated depreciation 992.1 842.5 1,193.0 1,028.3 Total property, plant and equipment, net $ 2,779.4 $ 2,917.1 $ 2,907.8 $ 3,061.3 Depreciation. CEQP’s depreciation expense totaled $180.9 million, $174.8 million and $139.5 million for the years ended December 31, 2021, 2020 and 2019. CMLP’s depreciation expense totaled $195.1 million, $188.9 million and $153.5 million for the years ended December 31, 2021, 2020 and 2019. Capitalized Interest. During the years ended December 31, 2021, 2020 and 2019, we capitalized interest of $0.4 million, $2.7 million and $14.4 million related to certain expansion projects. Intangible Assets Our intangible assets consisted of the following ( in millions ): December 31, 2021 2020 Customer accounts (1) $ 488.7 $ 488.7 Revenue contracts 631.2 631.2 Trademarks 6.2 6.2 1,126.1 1,126.1 Less: accumulated amortization 393.2 331.8 Total intangible assets, net $ 732.9 $ 794.3 (1) This amount includes $49.8 million related to customer accounts acquired in conjunction with the NGL Asset Acquisition which is further discussed in Note 3. The following table summarizes total accumulated amortization of our intangible assets ( in millions ): December 31, 2021 2020 Customer accounts $ 183.2 $ 158.5 Revenue contracts 204.6 168.6 Trademarks 5.4 4.7 Total accumulated amortization $ 393.2 $ 331.8 Amortization expense related to our intangible assets for the years ended December 31, 2021, 2020 and 2019, was approximately $61.4 million, $60.7 million and $54.6 million. Estimated amortization of our intangible assets for the next five years is as follows ( in millions ): Year Ending December 31, 2022 $ 61.4 2023 $ 57.6 2024 $ 54.2 2025 $ 51.5 2026 $ 51.3 Accrued Expenses and Other Liabilities Accrued expenses and other liabilities consisted of the following ( in millions ): December 31, 2021 2020 CMLP Accrued expenses $ 66.3 $ 45.4 Accrued property taxes 4.4 8.4 Income tax payable 0.4 0.2 Interest payable 30.6 24.9 Accrued additions to property, plant and equipment 17.4 12.3 Operating leases 13.2 14.7 Finance leases 1.7 2.9 Contract liabilities 10.7 10.3 Asset retirement obligations 1.4 1.0 Total CMLP accrued expenses and other liabilities $ 146.1 $ 120.1 CEQP Accrued expenses 0.9 1.9 Income tax payable 0.1 — Total CEQP accrued expenses and other liabilities $ 147.1 $ 122.0 Other Long-Term Liabilities Other long-term liabilities consisted of the following ( in millions ): December 31, 2021 2020 CMLP Contract liabilities $ 187.1 $ 172.2 Operating leases 19.4 28.5 Asset retirement obligations 34.8 34.1 Other 12.8 17.0 Total CMLP other long-term liabilities $ 254.1 $ 251.8 CEQP Other 4.6 1.5 Total CEQP other long-term liabilities $ 258.7 $ 253.3

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2021
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	Asset Retirement Obligations We have legal obligations associated with our facilities and right-of-way contracts we hold. Where we can reasonably estimate the ARO, we accrue a liability based on an estimate of the timing and amount of settlement. We record changes in these estimates based on changes in the expected amount and timing of payments to settle our obligations. We did not have any material assets that were legally restricted for use in settling asset retirement obligations as of December 31, 2021 and 2020. The following table presents the changes in our net asset retirement obligations ( in millions ): December 31, 2021 2020 Net asset retirement obligations at January 1 $ 35.1 $ 34.8 Liabilities acquired (1) — 0.3 Liabilities incurred — 0.3 Liabilities settled (0.4) (0.8) Accretion expense 1.9 1.9 Other (2) (0.4) (1.4) Net asset retirement obligations at December 31 (3) $ 36.2 $ 35.1 (1) Primarily relates to the NGL Asset Acquisition in 2020. See Note 3 for a further discussion of these acquisitions. (2) Relates to obligations associated with the abandonment and dismantlement of our Marcellus West Union compressor assets in 2021 as further discussed in Note 2 and the obligations included in the sale of our Fayetteville assets in 2020 as further discussed in Note 3. (3) Includes $1.4 million and $1.0 million of current ARO liabilities at December 31, 2021 and 2020.

Investments in Unconsolidated A

Investments in Unconsolidated Affiliates	12 Months Ended
	Dec. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Investments in Unconsolidated Affiliates	Investments in Unconsolidated Affiliates Stagecoach Gas Divestiture In July 2021, Stagecoach Gas Services LLC (Stagecoach Gas) sold certain of its wholly-owned subsidiaries to a subsidiary of Kinder Morgan, Inc. (Kinder Morgan) for approximately $1.195 billion plus certain purchase price adjustments (Initial Closing) pursuant to a purchase and sale agreement dated as of May 31, 2021 between our wholly-owned subsidiary, Crestwood Pipeline and Storage Northeast LLC (Crestwood Northeast), Con Edison Gas Pipeline and Storage Northeast, LLC (CEGP), a wholly-owned subsidiary of Consolidated Edison, Inc., Stagecoach Gas and Kinder Morgan. Following the Initial Closing, in November 2021 Crestwood Northeast and CEGP sold each of their equity interests in Stagecoach Gas and its wholly-owned subsidiary, Twin Tier Pipeline LLC, (Second Closing) to Kinder Morgan. We received cash proceeds of approximately $15.4 million related to the Second Closing. In conjunction with the Initial Closing and Second Closing, we recorded a $155.6 million reduction in our equity earnings from unconsolidated affiliates during the year ended December 31, 2021 related to losses recorded by us and our Stagecoach equity investment associated with the sale, which also eliminated our $51.3 million historical basis difference between our investment balance and the equity in the underlying net assets of Stagecoach Gas. In addition, our earnings from unconsolidated affiliates during the year ended December 31, 2021 were also reduced by our proportionate share of transaction costs of approximately $3.1 million related to the Initial Closing and Second Closing, which were paid by us during 2021 on behalf of Stagecoach Gas. Net Investments and Earnings (Loss) We account for each of our investments in unconsolidated affiliates under the equity method of accounting. Our Tres Palacios Holdings LLC (Tres Holdings), Powder River Basin Industrial Complex, LLC (PRBIC) and Stagecoach Gas (prior to its divestiture) equity investments are included in our storage and logistics segment. Our Crestwood Permian equity investment is included in our gathering and processing south segment. Our net investments in and earnings (loss) from our unconsolidated affiliates are as follows ( in millions, unless otherwise stated): Ownership Percentage Investment Earnings (Loss) from Unconsolidated Affiliates December 31, December 31, Year Ended December 31, 2021 2021 2020 2021 2020 2019 Stagecoach Gas Services LLC — % $ — $ 792.5 $ (139.2) $ 37.8 $ 34.2 Tres Palacios Holdings LLC 50.01 % 36.2 35.5 9.3 — 0.9 Powder River Basin Industrial Complex, LLC 50.01 % 3.5 3.6 (0.1) (4.3) (0.2) Crestwood Permian Basin Holdings LLC 50.00 % 116.1 112.1 9.6 (1.0) (5.8) Jackalope Gas Gathering Services, L.L.C. (1) — % — — — — 3.7 Total $ 155.8 $ 943.7 $ (120.4) $ 32.5 $ 32.8 (1) On April 9, 2019, Crestwood Niobrara acquired Williams’s 50% equity interest in Jackalope and, as a result, Crestwood Niobrara controls and owns 100% of the equity interests in Jackalope. Our Jackalope equity investment was previously included in our gathering and processing north segment. See Note 3 for a further discussion of this acquisition. Summarized Financial Information of Unconsolidated Affiliates Below is summarized financial information for our significant unconsolidated affiliates ( in millions; amounts represent 100% of unconsolidated affiliate information ): Financial Position Data December 31, 2021 2020 Current Assets Non-Current Assets Current Liabilities Non-Current Liabilities Members’ Equity Current Assets Non-Current Assets Current Liabilities Non-Current Liabilities Members’ Equity Stagecoach Gas (1) $ — $ — $ — $ — $ — $ 47.4 $ 1,645.5 $ 3.9 $ 1.4 $ 1,687.6 Other (2) 46.5 679.2 58.6 236.5 430.6 23.5 661.9 33.6 233.7 418.1 Total $ 46.5 $ 679.2 $ 58.6 $ 236.5 $ 430.6 $ 70.9 $ 2,307.4 $ 37.5 $ 235.1 $ 2,105.7 (1) As discussed above, in November 2021, we sold our equity interest in our Stagecoach Gas equity investment. (2) Includes our Tres Holdings, PRBIC and Crestwood Permian equity investments. As of December 31, 2021, our equity in the underlying net assets of Tres Holdings exceeded our investment balance by approximately $21.4 million. As of December 31, 2021, our equity in the underlying net assets of PRBIC approximates our investment balance. During the year ended December 31, 2020, we recorded our share of a long-lived asset impairment recorded by our PRBIC equity investment, which eliminated our $5.5 million historical basis difference between our investment and the equity in the underlying net assets of PRBIC. As of December 31, 2021, our equity in the underlying net assets of Crestwood Permian exceeded our investment balance by approximately $8.2 million, and this excess amount is not subject to amortization. Operating Results Data Year Ended December 31, 2021 2020 2019 Operating Revenues Operating Expenses Net Operating Revenues Operating Expenses Net Operating Revenues Operating Expenses Net Stagecoach Gas (1) $ 81.9 $ 456.7 $ (374.6) $ 154.3 $ 78.8 $ 75.5 $ 163.8 $ 83.6 $ 80.6 Other (2) 335.6 300.8 35.0 121.3 146.1 (24.6) 119.9 125.9 (6.0) Total $ 417.5 $ 757.5 $ (339.6) $ 275.6 $ 224.9 $ 50.9 $ 283.7 $ 209.5 $ 74.6 (1) As discussed above, in November 2021, we sold our equity interest in our Stagecoach Gas equity investment and, as a result, the information for the period ended 2021 is presented through November 24, 2021, the date of the Stagecoach Gas divestiture. (2) Includes our Tres Holdings, PRBIC, Crestwood Permian and Jackalope (prior to the acquisition of the remaining 50% interest from Williams in April 2019) equity investments. We amortize the excess basis in certain of our equity investments as an increase in our earnings from unconsolidated affiliates. We recorded amortization of the excess basis in our Tres Holdings equity investment of approximately $1.3 million for each of the years ended December 31, 2021, 2020 and 2019, which we amortize over the life of Tres Palacios’s sublease agreement. We recorded amortization of the excess basis in our PRBIC equity investment of approximately $0.4 million for the year ended December 31, 2019, which we amortized over the life of PRBIC’s property, plant and equipment. We recorded amortization of the excess basis in our Jackalope equity investment of less than $0.1 million for the year ended December 31, 2019, which we amortized over the life of Jackalope’s gathering and processing agreement with Chesapeake Energy Corporation. Distributions and Contributions Distributions (1) Contributions (2) Year Ended December 31, Year Ended December 31, 2021 2020 2019 2021 2020 2019 Stagecoach Gas $ 640.9 $ 59.7 $ 52.3 $ — $ — $ 2.1 Tres Holdings 15.5 6.4 6.3 6.9 6.0 6.3 PRBIC — 0.4 — — — 0.2 Crestwood Permian 16.3 11.9 5.0 10.7 3.4 28.3 Jackalope — — 11.6 — — 24.4 Total $ 672.7 $ 78.4 $ 75.2 $ 17.6 $ 9.4 $ 61.3 (1) In July 2021, Stagecoach Gas closed on the sale of certain of its wholly-owned subsidiaries to a subsidiary of Kinder Morgan and distributed to us approximately $613.9 million as our proportionate share of the gross proceeds received from the sale. We utilized approximately $3 million of these proceeds to pay transaction costs related to the sale described above, $40 million of these proceeds to pay our remaining contingent consideration obligation and related accrued interest described below, and the remaining proceeds to repay a portion of the amounts outstanding under the Crestwood Midstream credit facility. In January 2022, we received cash distributions from Crestwood Permian of approximately $8.5 million. (2) In January 2022, we made cash contributions of approximately $6.0 million and $8.5 million to our Tres Holdings and Crestwood Permian equity investments, respectively. Other

Risk Management

Risk Management	12 Months Ended
	Dec. 31, 2021
Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]
Risk Management	Risk Management We are exposed to certain market risks related to our ongoing business operations. These risks include exposure to changing commodity prices. We utilize derivative instruments to manage our exposure to fluctuations in commodity prices, which is discussed below. Additional information related to our derivatives is discussed in Note 2 and Note 8. Risk Management Activities We sell NGLs (such as propane, ethane, butane and heating oil), crude oil and natural gas to energy-related businesses and may use a variety of financial and other instruments including forward contracts involving physical delivery of NGLs, crude oil and natural gas. We periodically enter into offsetting positions to economically hedge against the exposure our customer contracts create. Certain of these contracts and positions are derivative instruments. We do not designate any of our commodity-based derivatives as hedging instruments for accounting purposes. Our commodity-based derivatives are reflected at fair value in our consolidated balance sheets, and changes in the fair value of these derivatives that impact our consolidated statements of operations are reflected in costs of product/services sold. Our commodity-based derivatives that are settled with physical commodities are reflected as an increase to product revenues, and the commodity inventory that is utilized to satisfy those physical obligations is reflected as an increase to product costs in our consolidated statements of operations. The following table summarizes the impact to our consolidated statements of operations related to our commodity-based derivatives during the years ended December 31, 2021, 2020 and 2019 ( in millions ): December 31, 2021 2020 2019 Product revenues $ 486.7 $ 214.3 $ 252.3 Gain (loss) reflected in product costs $ (44.5) $ (20.7) $ 19.5 We attempt to balance our contractual portfolio in terms of notional amounts and timing of performance and delivery obligations. This balance in the contractual portfolio significantly reduces the volatility in product costs related to these instruments. Notional Amounts and Terms The notional amounts of our derivative financial instruments include the following: December 31, 2021 December 31, 2020 Fixed Price Fixed Price Fixed Price Fixed Price Propane, ethane, butane, heating oil and crude oil (MMBbls) 71.6 75.8 72.7 76.5 Natural gas (Bcf) 31.9 43.4 22.6 28.6 Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly, notional amounts do not reflect our monetary exposure to market or credit risks. All contracts subject to price risk had a maturity of 37 months or less; however, 87% of the contracted volumes will be delivered or settled within 12 months. Credit Risk Inherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. The counterparties associated with our price risk management activities are energy marketers and propane retailers, resellers and dealers. Certain of our derivative instruments have credit limits that require us to post collateral. The amount of collateral required to be posted is a function of the net liability position of the derivative as well as our established credit limit with the respective counterparty. If our credit rating were to change, the counterparties could require us to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent of change in our credit rating as well as the requirements of the individual counterparty. In addition, we have margin requirements with a derivative clearing broker and a third party broker related to our net asset or liability position with each respective broker. All collateral amounts have been netted against the asset or liability with the respective counterparty and are reflected in our consolidated balance sheets as assets and liabilities from price risk management activities. The following table presents the fair value of our commodity derivative instruments with credit-risk-related contingent features and their associated collateral ( in millions ): December 31, 2021 2020 Aggregate fair value liability of derivative instruments with credit-risk-related contingent features (1) $ 57.9 $ 38.5 Broker-related net derivative asset position $ 104.8 $ 35.9 Broker-related cash collateral received $ 76.8 $ 18.3 Cash collateral received, net $ 11.4 $ 12.4 (1) At December 31, 2021 and 2020, we posted $1.5 million and less than $0.1 million of collateral associated with these derivatives.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The accounting standard for fair value measurement establishes a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows: • Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for Level 1 primarily consists of financial instruments such as exchange-traded derivatives, listed equities and US government treasury securities. • Level 2—Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives such as over the counter (OTC) forwards, options and physical exchanges. • Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. Financial Assets and Liabilities As of December 31, 2021 and 2020, we held certain assets and liabilities that are required to be measured at fair value on a recurring basis, which include our derivative instruments related to crude oil, NGLs and natural gas. Our derivative instruments consist of forwards, swaps, futures, physical exchanges and options. Our derivative instruments that are traded on the NYMEX have been categorized as Level 1. Our derivative instruments also include OTC contracts, which are not traded on a public exchange. The fair values of these derivative instruments are determined based on inputs that are readily available in public markets or can be derived from information available in publicly quoted markets. These instruments have been categorized as Level 2. Our OTC options are valued based on the Black Scholes option pricing model that considers time value and volatility of the underlying commodity. The inputs utilized in the model are based on publicly available information as well as broker quotes. These options have been categorized as Level 2. Our financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The following tables set forth by level within the fair value hierarchy, our financial instruments that were accounted for at fair value on a recurring basis at December 31, 2021 and 2020 ( in millions ): December 31, 2021 Level 1 Level 2 Level 3 Gross Fair Value Contract Netting (1) Collateral/Margin Received or Paid Fair Value Assets Assets from price risk management $ 33.3 $ 695.6 $ — $ 728.9 $ (607.4) $ (79.4) $ 42.1 Other investments (2) 2.2 — — 2.2 — — 2.2 Total assets at fair value $ 35.5 $ 695.6 $ — $ 731.1 $ (607.4) $ (79.4) $ 44.3 Liabilities Liabilities from price risk management $ 26.9 $ 686.3 $ — $ 713.2 $ (607.4) $ 8.8 $ 114.6 Total liabilities at fair value $ 26.9 $ 686.3 $ — $ 713.2 $ (607.4) $ 8.8 $ 114.6 December 31, 2020 Level 1 Level 2 Level 3 Gross Fair Value Contract Netting (1) Collateral/Margin Received or Paid Fair Value Assets Assets from price risk management $ 20.2 $ 480.5 $ — $ 500.7 $ (455.0) $ (18.5) $ 27.2 Other investments (2) 2.1 — — 2.1 — — 2.1 Total assets at fair value $ 22.3 $ 480.5 $ — $ 502.8 $ (455.0) $ (18.5) $ 29.3 Liabilities Liabilities from price risk management $ 25.1 $ 494.0 $ — $ 519.1 $ (455.0) $ 12.2 $ 76.3 Total liabilities at fair value $ 25.1 $ 494.0 $ — $ 519.1 $ (455.0) $ 12.2 $ 76.3 (1) Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions. (2) Amount primarily relates to our investment in Suburban Propane Partners, L.P. units which is reflected in other non-current assets on CEQP’s consolidated balance sheets. Cash, Accounts Receivable and Accounts Payable As of December 31, 2021 and 2020, the carrying amounts of cash, accounts receivable and accounts payable approximate fair value based on the short-term nature of these instruments. Credit Facility The fair value of the amounts outstanding under our Crestwood Midstream credit facility approximates the carrying amounts as of December 31, 2021 and 2020, due primarily to the variable nature of the interest rate of the instrument, which is considered a Level 2 fair value measurement. Senior Notes We estimate the fair value of our senior notes primarily based on quoted market prices for the same or similar issuances (representing a Level 2 fair value measurement). The following table represents the carrying amount (reduced for deferred financing costs associated with the respective notes) and fair value of our senior notes ( in millions ): December 31, 2021 December 31, 2020 Carrying Amount Fair Carrying Amount Fair 2023 Senior Notes $ — $ — $ 683.8 $ 691.5 2025 Senior Notes $ 496.5 $ 511.9 $ 495.5 $ 509.9 2027 Senior Notes $ 594.2 $ 615.0 $ 593.2 $ 594.1 2029 Senior Notes $ 690.8 $ 727.3 $ — $ —

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt consisted of the following ( in millions ): December 31, 2021 2020 Credit Facility $ 282.0 $ 719.0 2023 Senior Notes — 687.2 2025 Senior Notes 500.0 500.0 2027 Senior Notes 600.0 600.0 2029 Senior Notes 700.0 — Other (1) 0.2 0.4 Less: deferred financing costs, net 29.9 22.6 Total debt 2,052.3 2,484.0 Less: current portion 0.2 0.2 Total long-term debt, less current portion $ 2,052.1 $ 2,483.8 (1) Represents non-interest bearing obligations related to certain companies acquired in 2014 with payments due through 2022. Credit Facility In December 2021, Crestwood Midstream entered into a Third Amended and Restated Credit Agreement (the CMLP Credit Agreement). The CMLP Credit Agreement provides for a five-year $1.5 billion revolving credit facility (the CMLP Credit Facility), which matures in December 2026 and is available to fund acquisitions, working capital and internal growth projects and for general partnership purposes. The CMLP Credit Agreement increased from $1.25 billion to $1.5 billion upon the closing of the merger with Oasis Midstream Partners LP (Oasis Midstream) on February 1, 2022, which is further discussed in Note 20. The credit agreement allows Crestwood Midstream to increase its available borrowings under the facility by $350 million, subject to lender approval and the satisfaction of certain other conditions, as described in the credit agreement. The CMLP Credit Facility also includes a sub-limit of up to $25 million for same-day swing line advances and a sub-limit up to $350 million for letters of credit. Subject to limited exception, the CMLP Credit Facility is guaranteed and secured by substantially all of the equity interests and assets of Crestwood Midstream’s subsidiaries, except for Crestwood Infrastructure Holdings LLC, Crestwood Niobrara, PRBIC and Tres Holdings and their respective subsidiaries. Crestwood Equity also guarantees Crestwood Midstream’s payment obligations under its $1.5 billion credit agreement. We recognized a loss on extinguishment of debt of approximately $0.8 million for the year ended December 31, 2021 in conjunction with amending and restating the CMLP Credit Agreement. Prior to amending and restating its credit agreement in December 2021, Crestwood Midstream had a five-year $1.25 billion senior secured revolving credit facility, which would have expired in October 2023 (2023 Credit Facility). Contemporaneous with the Crestwood Holdings Transactions in March 2021, Crestwood Midstream amended the 2023 Credit Facility in order to, among other things, permit the borrowings under the 2023 Credit Facility to fund the Crestwood Holdings Transactions and revise the definition of Change in Control in the credit agreement as it relates to the control of CEQP’s general partner. The CMLP Credit Agreement contains various covenants and restrictive provisions that limit our ability to, among other things, (i) incur additional debt; (ii) make distributions on or redeem or repurchase units; (iii) make certain investments and acquisitions; (iv) incur or permit certain liens to exist; (v) merge, consolidate or amalgamate with another company; (vi) transfer or dispose of assets; and (vii) incur a change in control at either Crestwood Equity or Crestwood Midstream. Borrowings under the CMLP Credit Facility (other than the swing line loans) bear interest at either: • the Alternate Base Rate, which is defined as the highest of (i) the federal funds rate plus 0.50%; (ii) Wells Fargo Bank’s prime rate; or (iii) the Adjusted Term SOFR (as defined in the credit agreement) for a one-month tenor plus 1% per annum; plus a margin varying from 0.50% to 1.50% depending on Crestwood Midstream’s most recent consolidated total leverage ratio; or • Adjusted Term SOFR plus a margin varying from 1.50% to 2.50% depending on Crestwood Midstream’s most recent consolidated total leverage ratio. Swing line loans bear interest at the Alternate Base Rate as described above. The unused portion of the CMLP Credit Facility is subject to a commitment fee ranging from 0.30% to 0.50% according to CMLP’s most recent consolidated total leverage ratio. Interest on the Alternate Base Rate loans is payable quarterly, or if the Adjusted Term SOFR applies, interest is payable at certain intervals selected by Crestwood Midstream. Crestwood Midstream is required under its credit agreement to maintain a net debt to consolidated EBITDA ratio (as defined in its credit agreement) of not more than 5.50 to 1.0, a consolidated EBITDA to consolidated interest expense ratio (as defined in its credit agreement) of not less than 2.50 to 1.0, and a senior secured leverage ratio (as defined in its credit agreement) of not more than 3.50 to 1.0. At December 31, 2021, the net debt to consolidated EBITDA was approximately 3.53 to 1.0, the consolidated EBITDA to consolidated interest expense was approximately 4.93 to 1.0, and the senior secured leverage ratio was 0.48 to 1.0. At December 31, 2021, Crestwood Midstream had $961.7 million of available capacity under its credit facility considering the most restrictive covenants in its credit agreement. At December 31, 2021 and 2020, Crestwood Midstream’s outstanding standby letters of credit were $6.3 million and $23.9 million. The interest rates on borrowings under the credit facility were between 1.90% and 4.00% at December 31, 2021 and 2.40% and 4.50% at December 31, 2020. The weighted-average interest rates on outstanding borrowings as of December 31, 2021 and 2020 was 1.91% and 2.45%. If Crestwood Midstream fails to perform its obligations under these and other covenants, the lenders’ credit commitment could be terminated and any outstanding borrowings, together with accrued interest, under the CMLP Credit Facility could be declared immediately due and payable. The CMLP Credit Facility also has cross default provisions that apply to any of its other material indebtedness. Senior Notes 2023 Senior Notes . The 6.25% Senior Notes due 2023 (the 2023 Senior Notes) were scheduled to mature on April 1, 2023. During the year ended December 31, 2021, we redeemed $687.2 million of principal under the 2023 Senior Notes. In conjunction with the repayment of the notes, we recognized a loss on extinguishment of debt of approximately $6.7 million during the year ended December 31, 2021, and paid approximately $8.6 million of accrued interest on the 2023 Senior Notes on the dates they were repurchased. We funded the repayment using a portion of the proceeds from the issuance of the 2029 Senior Notes (described below) and borrowings under the 2023 Credit Facility. During the year ended December 31, 2020, we paid approximately $12.6 million to repurchase and cancel approximately $12.8 million of the 2023 Senior Notes. 2025 Senior Notes. The 5.75% Senior Notes due 2025 (the 2025 Senior Notes) mature on April 1, 2025, and interest is payable semi-annually in arrears on April 1 and October 1 of each year. 2027 Senior Notes. In April 2019, Crestwood Midstream issued $600 million of 5.625% unsecured senior notes due 2027 (the 2027 Senior Notes). The 2027 Senior Notes mature on May 1, 2027, and interest is payable semi-annually in arrears on May 1 and November 1 of each year, beginning November 1, 2019. The net proceeds from this offering of approximately $591.1 million were used to fund the acquisition of the remaining 50% equity interest in Jackalope. 2029 Senior Notes. In January 2021, Crestwood Midstream issued $700 million of 6.00% unsecured senior notes due 2029 (the 2029 Senior Notes). The 2029 Senior Notes mature on February 1, 2029, and interest is payable semiannually in arrears on February 1 and August 1 of each year, beginning on August 1, 2021. The net proceeds from this offering of approximately $691.0 million were used to repay a portion of the 2023 Senior Notes and to repay indebtedness under the 2023 Credit Facility. In general, each series of Crestwood Midstream’s senior notes are fully and unconditionally guaranteed, joint and severally, on a senior unsecured basis by Crestwood Midstream’s domestic restricted subsidiaries (other than Crestwood Midstream Finance Corp., which has no assets). The indentures contain customary release provisions, such as (i) disposition of all or substantially all the assets of, or the capital stock of, a guarantor subsidiary to a third person if the disposition complies with the indentures; (ii) designation of a guarantor subsidiary as an unrestricted subsidiary in accordance with its indentures; (iii) legal or covenant defeasance of a series of senior notes, or satisfaction and discharge of the related indenture; and (iv) guarantor subsidiary ceases to guarantee any other indebtedness of Crestwood Midstream or any other guarantor subsidiary, provided it no longer guarantees indebtedness under the CMLP Credit Facility. The indentures restrict the ability of Crestwood Midstream and its restricted subsidiaries to, among other things, sell assets; redeem or repurchase subordinated debt; make investments; incur or guarantee additional indebtedness or issue preferred units; create or incur certain liens; enter into agreements that restrict distributions or other payments to Crestwood Midstream from its restricted subsidiaries; consolidate, merge or transfer all or substantially all of their assets; engage in affiliate transactions; create unrestricted subsidiaries; and incur a change in control at either Crestwood Equity or Crestwood Midstream. These restrictions are subject to a number of exceptions and qualifications, and many of these restrictions will terminate when the senior notes are rated investment grade by either Moody’s Investors Service, Inc. or Standard & Poor’s Rating Services and no default or event of default (each as defined in the respective indentures) under the indentures has occurred and is continuing. At December 31, 2021, Crestwood Midstream was in compliance with the debt covenants and restrictions in each of its credit agreements discussed above. The CMLP Credit Facility and senior notes are secured by the net assets of its guarantor subsidiaries. Accordingly, such assets are only available to the creditors of Crestwood Midstream. Crestwood Equity had restricted net assets of approximately $1,232.3 million as of December 31, 2021. Maturities The aggregate maturities of principal amounts on our outstanding long-term debt as of December 31, 2021 for the next five years and in total thereafter are as follows ( in millions ): 2022 $ 0.2 2023 — 2024 — 2025 500.0 2026 282.0 Thereafter 1,300.0 Total debt $ 2,082.2

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Legal Proceedings Oasis Unitholder Lawsuit. On December 17, 2021, Kristen Eckert-Smith (Plaintiff), a common unitholder of Oasis Midstream filed a complaint in the United States District Court for the District of Delaware on behalf of all Oasis common unitholders. This complaint alleges that the merger between Oasis Midstream and Crestwood Equity violates the Securities Exchange Act of 1934. In addition, the Plaintiff filed a lawsuit against Oasis Midstream, its board of directors and Crestwood Equity GP, claiming the Registration Statement filed with the SEC omitted material information with respect to Oasis Midstream’s calculated projections and financial analyses. The Plaintiff is seeking to block the parties from closing the merger and in the alternative, to revise the Registration Statement and award plaintiff the attorney’s and expert’s fees. We are currently evaluating the potential impact of this lawsuit, but currently do not believe it will have a material impact on our financial condition or results of operations. Linde Lawsuit . On December 23, 2019, Linde Engineering North America Inc. (Linde) filed a lawsuit in the District Court of Harris County, Texas alleging that Arrow Field Services, LLC, our consolidated subsidiary, and Crestwood Midstream breached a contract entered into in March 2018 under which Linde was to provide engineering, procurement and construction services to us related to the completion of the construction of the Bear Den II cryogenic processing plant. During the year ended December 31, 2021, we paid approximately $19.5 million to Linde related to this matter, and Linde claims remaining unpaid invoices of approximately $36 million, along with other damages. This matter is not an insurable event based on our insurance policies, and we are unable to predict the outcome for this matter. General . We are periodically involved in litigation proceedings. If we determine that a negative outcome is probable and the amount of loss is reasonably estimable, then we accrue the estimated amount. The results of litigation proceedings cannot be predicted with certainty. We could incur judgments, enter into settlements or revise our expectations regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations or cash flows in the period in which the amounts are paid and/or accrued. As of December 31, 2021 and 2020, we had approximately $16.8 million and $10.4 million accrued for outstanding legal matters. Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures for which we can estimate will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures. Any loss estimates are inherently subjective, based on currently available information, and are subject to management’s judgment and various assumptions. Due to the inherently subjective nature of these estimates and the uncertainty and unpredictability surrounding the outcome of legal proceedings, actual results may differ materially from any amounts that have been accrued. Regulatory Compliance In the ordinary course of our business, we are subject to various laws and regulations. In the opinion of our management, compliance with current laws and regulations will not have a material effect on our results of operations, cash flows or financial condition. Environmental Compliance Our operations are subject to stringent and complex laws and regulations pertaining to worker health, safety, and the environment. We are subject to laws and regulations at the federal, state, regional and local levels that relate to air and water quality, hazardous and solid waste management and disposal, and other environmental matters. The cost of planning, designing, constructing and operating our facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures. During 2019, we experienced two produced water releases on our Arrow water gathering system located within the Fort Berthold Indian Reservation in North Dakota. In January 2021, we received a Notice of Violation and Opportunity to Confer from the EPA related to the water releases. In March 2021, we executed a Consent Agreement with the EPA and in January 2022, we paid approximately $0.1 million in civil penalties to resolve the matter. We are also substantially complete with all remediation efforts related to the water releases and continue to monitor any remaining impacts. We believe these events are insurable under our policies. We have not recorded an insurance receivable as of December 31, 2021. At December 31, 2021 and 2020, our accrual of approximately $1.0 million and $1.3 million was based on our undiscounted estimate of amounts we will spend on compliance with environmental and other regulations, and any associated fines or penalties. We estimate that our potential liability for reasonably possible outcomes related to our environmental exposures could range from approximately $1.0 million to $1.9 million at December 31, 2021. Self-Insurance We utilize third-party insurance subject to varying retention levels of self-insurance, which management considers prudent. Such self-insurance relates to losses and liabilities primarily associated with medical claims, workers’ compensation claims and general, product, vehicle and environmental liability. Losses are accrued based upon management’s estimates of the aggregate liability for claims incurred using certain assumptions followed in the insurance industry and based on past experience. The primary assumption utilized is actuarially determined loss development factors. The loss development factors are based primarily on historical data. Our self-insurance reserves could be affected if future claim developments differ from the historical trends. We believe changes in health care costs, trends in health care claims of our employee base, accident frequency and severity and other factors could materially affect the estimate for these liabilities. We continually monitor changes in employee demographics, incident and claim type and evaluate our insurance accruals and adjust our accruals based on our evaluation of these qualitative data points. We are liable for the development of claims for our previously disposed of retail propane operations, provided they were reported prior to August 1, 2012. The following table summarizes CEQP’s and CMLP’s self-insurance reserves (in millions) : CEQP CMLP December 31, December 31, 2021 2020 2021 2020 Self-insurance reserves (1) $ 5.5 $ 7.7 $ 4.7 $ 6.7 (1) At December 31, 2021, CEQP and CMLP classified approximately $3.5 million and $2.9 million, respectively of these reserves as other long-term liabilities on their consolidated balance sheets. Purchase Commitments We periodically enter into agreements with suppliers to purchase fixed quantities of NGLs, distillates, crude oil and natural gas at fixed prices. At December 31, 2021, the total of these firm purchase commitments was $2,760.9 million, of which approximately $2,493.6 million will occur over the next twelve months. We also enter into non-binding agreements with suppliers to purchase quantities of NGLs, distillates, crude oil and natural gas at variable prices at future dates at the then prevailing market prices. We have entered into certain purchase commitments which totaled approximately $15.6 million at December 31, 2021. These purchase commitments primarily relate to future growth projects and maintenance obligations in our gathering and processing north segment. The purchases associated with our commitments are expected to occur over the next twelve months. Guarantees and Indemnifications We are involved in various joint ventures that sometimes require financial and performance guarantees. In a financial guarantee, we are obligated to make payments if the guaranteed party fails to make payments under, or violates the terms of, the financial arrangement. In a performance guarantee, we provide assurance that the guaranteed party will execute on the terms of the contract. If they do not, we are required to perform on their behalf. We also periodically provide indemnification arrangements related to assets or businesses we have sold. Our potential exposure under guarantee and indemnification arrangements can range from a specified amount to an unlimited dollar amount, depending on the nature of the claim, specificity as to duration, and the particular transaction. As of December 31, 2021, we have no amounts accrued for these guarantees.

Leases

Leases	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Leases	Leases The following table summarizes the balance sheet information related to our operating and finance leases ( in millions ): December 31, 2021 2020 Operating leases Operating lease right-of-use assets, net $ 27.4 $ 36.8 Accrued expenses and other liabilities $ 13.2 $ 14.7 Other long-term liabilities 19.4 28.5 Total operating lease liabilities $ 32.6 $ 43.2 Finance leases Property, plant and equipment $ 12.3 $ 13.3 Less: accumulated depreciation 9.2 7.9 Property, plant and equipment, net $ 3.1 $ 5.4 Accrued expenses and other liabilities $ 1.7 $ 2.9 Other long-term liabilities 1.2 1.9 Total finance lease liabilities $ 2.9 $ 4.8 The following table presents the weighted-average remaining lease term and the weighted-average discount rate associated with our operating and finance leases: December 31, 2021 2020 Weighted-average remaining lease term (in years) Operating leases (1) 3.9 4.3 Finance leases (2) 2.6 1.7 Weighted-average discount rate Operating leases (3) 5.9 % 6.2 % Finance leases (3) 5.5 % 7.3 % (1) Remaining terms vary from one year to 18 years as of December 31, 2021. (2) Remaining terms vary from one year to five years as of December 31, 2021. (3) As of December 31, 2021 and 2020, we utilized discount rates ranging from 1.5% to 8.3% and 2.6% to 12.8%, respectively, to estimate the discounted cash flows used in estimating our right-of-use assets and lease liabilities, which were primarily based on our credit-adjusted collateralized incremental borrowing rate. The estimation of our right-of-use assets and lease liabilities requires us to make significant assumptions and judgments about the terms of the leases, variable payments, and discount rates. Certain of our operating leases have renewal options to extend the leases from one year to 10 years at the end of each lease term, or terminate the leases at our sole discretion. In addition, certain of our finance leases have options to purchase the lease property by the end of the lease term. We make significant assumptions on the likelihood on whether we will renew our leases or purchase the property at the end of the lease terms in determining the discounted cash flows to measure our right-of-use assets and lease liabilities. The estimation of variable lease payments in determining discounted cash flows, including those with usage-based costs, also requires us to make significant assumptions on the timing and nature of the variability of those payments based on the lease terms. We recognize operating lease expense and amortize our right-of-use assets for our finance leases on a straight-line basis over the term of the respective leases. We have applied the practical expedient of not separating the lease and non-lease components for our leases where the predominant consideration paid related to the underlying operating and finance lease contracts relate to the lease component. The following table presents the costs and sublease income associated with our operating and finance leases ( in millions ): Year Ended December 31, 2021 2020 2019 Operating leases Operating lease expense (1)(2) $ 20.0 $ 27.2 $ 28.3 Lease income (3) (3.7) (1.7) (1.0) Total operating lease expense, net $ 16.3 $ 25.5 $ 27.3 Finance leases Amortization of right-of-use assets (4) $ 3.0 $ 3.5 $ 3.6 Interest on lease liabilities (5) 0.3 0.5 0.7 Total finance lease expense $ 3.3 $ 4.0 $ 4.3 (1) Approximately $13.4 million, $17.6 million and $17.5 million is included in costs of product/services sold, $3.9 million, $6.7 million and $8.0 million is included in operations and maintenance expense and $2.7 million, $2.9 million and $2.8 million is included in general and administrative expense on our consolidated statements of operations for the years ended December 31, 2021, 2020 and 2019, respectively. (2) Includes short-term and variable lease costs of approximately $2.2 million, $5.5 million and $3.7 million for the years ended December 31, 2021, 2020 and 2019. (3) Included in service revenues on our consolidated statements of operations. (4) Included in depreciation, amortization and accretion expense on our consolidated statements of operations. (5) Included in interest and debt expense, net on our consolidated statements of operations. The following table presents supplemental cash flow information for our operating and finance leases ( in millions ): Year Ended December 31, 2021 2020 2019 Cash paid for lease liabilities Operating cash flows from operating leases $ 19.0 $ 21.3 $ 22.9 Operating cash flows from finance leases $ 0.3 $ 0.5 $ 0.7 Financing cash flows from finance leases $ 2.8 $ 3.1 $ 3.5 Right-of-use assets obtained in exchange for lease obligations Operating leases $ — $ 2.1 $ 4.2 Finance leases $ 1.5 $ 0.4 $ 1.8 The following table presents the future minimum lease liabilities for our leases as of December 31, 2021 for the next five years and in total thereafter ( in millions ): Year Ending December 31, Operating Leases Finance Leases Total 2022 $ 14.6 $ 1.8 $ 16.4 2023 7.5 0.5 8.0 2024 6.6 0.3 6.9 2025 3.2 0.3 3.5 2026 3.0 0.2 3.2 Thereafter 2.0 — 2.0 Total lease payments 36.9 3.1 40.0 Less: interest 4.3 0.2 4.5 Present value of lease liabilities $ 32.6 $ 2.9 $ 35.5
Leases	Leases The following table summarizes the balance sheet information related to our operating and finance leases ( in millions ): December 31, 2021 2020 Operating leases Operating lease right-of-use assets, net $ 27.4 $ 36.8 Accrued expenses and other liabilities $ 13.2 $ 14.7 Other long-term liabilities 19.4 28.5 Total operating lease liabilities $ 32.6 $ 43.2 Finance leases Property, plant and equipment $ 12.3 $ 13.3 Less: accumulated depreciation 9.2 7.9 Property, plant and equipment, net $ 3.1 $ 5.4 Accrued expenses and other liabilities $ 1.7 $ 2.9 Other long-term liabilities 1.2 1.9 Total finance lease liabilities $ 2.9 $ 4.8 The following table presents the weighted-average remaining lease term and the weighted-average discount rate associated with our operating and finance leases: December 31, 2021 2020 Weighted-average remaining lease term (in years) Operating leases (1) 3.9 4.3 Finance leases (2) 2.6 1.7 Weighted-average discount rate Operating leases (3) 5.9 % 6.2 % Finance leases (3) 5.5 % 7.3 % (1) Remaining terms vary from one year to 18 years as of December 31, 2021. (2) Remaining terms vary from one year to five years as of December 31, 2021. (3) As of December 31, 2021 and 2020, we utilized discount rates ranging from 1.5% to 8.3% and 2.6% to 12.8%, respectively, to estimate the discounted cash flows used in estimating our right-of-use assets and lease liabilities, which were primarily based on our credit-adjusted collateralized incremental borrowing rate. The estimation of our right-of-use assets and lease liabilities requires us to make significant assumptions and judgments about the terms of the leases, variable payments, and discount rates. Certain of our operating leases have renewal options to extend the leases from one year to 10 years at the end of each lease term, or terminate the leases at our sole discretion. In addition, certain of our finance leases have options to purchase the lease property by the end of the lease term. We make significant assumptions on the likelihood on whether we will renew our leases or purchase the property at the end of the lease terms in determining the discounted cash flows to measure our right-of-use assets and lease liabilities. The estimation of variable lease payments in determining discounted cash flows, including those with usage-based costs, also requires us to make significant assumptions on the timing and nature of the variability of those payments based on the lease terms. We recognize operating lease expense and amortize our right-of-use assets for our finance leases on a straight-line basis over the term of the respective leases. We have applied the practical expedient of not separating the lease and non-lease components for our leases where the predominant consideration paid related to the underlying operating and finance lease contracts relate to the lease component. The following table presents the costs and sublease income associated with our operating and finance leases ( in millions ): Year Ended December 31, 2021 2020 2019 Operating leases Operating lease expense (1)(2) $ 20.0 $ 27.2 $ 28.3 Lease income (3) (3.7) (1.7) (1.0) Total operating lease expense, net $ 16.3 $ 25.5 $ 27.3 Finance leases Amortization of right-of-use assets (4) $ 3.0 $ 3.5 $ 3.6 Interest on lease liabilities (5) 0.3 0.5 0.7 Total finance lease expense $ 3.3 $ 4.0 $ 4.3 (1) Approximately $13.4 million, $17.6 million and $17.5 million is included in costs of product/services sold, $3.9 million, $6.7 million and $8.0 million is included in operations and maintenance expense and $2.7 million, $2.9 million and $2.8 million is included in general and administrative expense on our consolidated statements of operations for the years ended December 31, 2021, 2020 and 2019, respectively. (2) Includes short-term and variable lease costs of approximately $2.2 million, $5.5 million and $3.7 million for the years ended December 31, 2021, 2020 and 2019. (3) Included in service revenues on our consolidated statements of operations. (4) Included in depreciation, amortization and accretion expense on our consolidated statements of operations. (5) Included in interest and debt expense, net on our consolidated statements of operations. The following table presents supplemental cash flow information for our operating and finance leases ( in millions ): Year Ended December 31, 2021 2020 2019 Cash paid for lease liabilities Operating cash flows from operating leases $ 19.0 $ 21.3 $ 22.9 Operating cash flows from finance leases $ 0.3 $ 0.5 $ 0.7 Financing cash flows from finance leases $ 2.8 $ 3.1 $ 3.5 Right-of-use assets obtained in exchange for lease obligations Operating leases $ — $ 2.1 $ 4.2 Finance leases $ 1.5 $ 0.4 $ 1.8 The following table presents the future minimum lease liabilities for our leases as of December 31, 2021 for the next five years and in total thereafter ( in millions ): Year Ending December 31, Operating Leases Finance Leases Total 2022 $ 14.6 $ 1.8 $ 16.4 2023 7.5 0.5 8.0 2024 6.6 0.3 6.9 2025 3.2 0.3 3.5 2026 3.0 0.2 3.2 Thereafter 2.0 — 2.0 Total lease payments 36.9 3.1 40.0 Less: interest 4.3 0.2 4.5 Present value of lease liabilities $ 32.6 $ 2.9 $ 35.5

Partners' Capital and Non-Contr

Partners' Capital and Non-Controlling Partner	12 Months Ended
	Dec. 31, 2021
Partners' Capital [Abstract]
Partners' Capital	Partners’ Capital and Non-Controlling Partner Preferred Units Subject to certain conditions, the holders of the preferred units will have the right to convert preferred units into (i) common units on a 1-for-10 basis, or (ii) a number of common units determined pursuant to a conversion ratio set forth in Crestwood Equity’s partnership agreement upon the occurrence of certain events, such as a change in control. The preferred units have voting rights that are identical to the voting rights of the common units and will vote with the common units as a single class, with each preferred units entitled to one vote for each common unit into which such preferred unit is convertible, except that the preferred units are entitled to vote as a separate class on any matter on which all unitholders are entitled to vote that adversely affects the rights, powers, privileges or preferences of the preferred units in relation to CEQP’s other securities outstanding. Common and Subordinated Units In conjunction with the Crestwood Holdings Transactions discussed in Note 1, in March 2021, CEQP acquired approximately 11.5 million CEQP common units and 0.4 million subordinated units of CEQP from Crestwood Holdings for approximately $268 million. CEQP reflected the purchase price as a reduction to its common unitholders’ partners’ capital in its consolidated statement of partners’ capital during the year ended December 31, 2021. The Crestwood Holdings Transactions resulted in CEQP retiring the common and subordinated units acquired from Crestwood Holdings. Transaction costs related to the Crestwood Holdings Transactions of approximately $7.6 million are reflected as a reduction of CEQP’s common unitholders’ partners’ capital in its consolidated statement of partners’ capital during the year ended December 31, 2021. Distributions Crestwood Equity Limited Partners . Crestwood Equity makes quarterly distributions to its partners within approximately 45 days after the end of each quarter in an aggregate amount equal to its available cash for such quarter. Available cash generally means, with respect to each quarter, all cash on hand at the end of the quarter less the amount of cash that the general partner determines in its reasonable discretion is necessary or appropriate to: • provide for the proper conduct of its business; • comply with applicable law, any of its debt instruments, or other agreements; or • provide funds for distributions to unitholders for any one or more of the next four quarters; plus all cash on hand on the date of determination of available cash for the quarter resulting from working capital borrowings made after the end of the quarter. The amount of cash CEQP has available for distribution depends primarily upon its cash flow (which consists of the cash distributions it receives in connection with its ownership of Crestwood Midstream). A summary of CEQP’s limited partner quarterly cash distributions for the years ended December 31, 2021, 2020 and 2019 is presented below: Record Date Payment Date Per Unit Rate Cash Distributions ( in millions ) 2021 February 5, 2021 February 12, 2021 $ 0.625 $ 46.4 May 7, 2021 May 14, 2021 $ 0.625 39.3 August 6, 2021 August 13, 2021 $ 0.625 39.3 November 5, 2021 November 12, 2021 $ 0.625 39.3 $ 164.3 2020 February 7, 2020 February 14, 2020 $ 0.625 $ 45.3 May 8, 2020 May 15, 2020 $ 0.625 45.7 August 7, 2020 August 14, 2020 $ 0.625 45.7 November 6, 2020 November 13, 2020 $ 0.625 46.0 $ 182.7 2019 February 7, 2019 February 14, 2019 $ 0.60 $ 43.1 May 8, 2019 May 15, 2019 $ 0.60 43.1 August 7, 2019 August 14, 2019 $ 0.60 43.1 November 7, 2019 November 14, 2019 $ 0.60 43.1 $ 172.4 On February 14, 2022, we paid a distribution of $0.625 per limited partner unit to unitholders of record on February 7, 2022 with respect to the fourth quarter of 2021. Preferred Unitholders . The holders of our preferred units are entitled to receive fixed quarterly distributions of $0.2111 per unit. Distributions on the preferred units are paid in cash unless, subject to certain exceptions, (i) there is no distribution being paid on our common units; and (ii) our available cash (as defined in our partnership agreement) is insufficient to make a cash distribution to our preferred unitholders. If we fail to pay the full amount payable to our preferred unitholders in cash, then (x) the fixed quarterly distribution on the preferred units will increase to $0.2567 per unit, and (y) we will not be permitted to declare or make any distributions to our common unitholders until such time as all accrued and unpaid distributions on the preferred units have been paid in full in cash. In addition, if we fail to pay in full any preferred distribution (as defined in our partnership agreement), the amount of such unpaid distribution will accrue and accumulate from the last day of the quarter for which such distribution is due until paid in full, and any accrued and unpaid distributions will be increased at a rate of 2.8125% per quarter. During each of the years ended December 31, 2021, 2020 and 2019, we paid cash distributions to our preferred unitholders of approximately $60.1 million. On February 14, 2022, we made a cash distribution of approximately $15.0 million to our preferred unitholders with respect to the fourth quarter of 2021. Crestwood Midstream In accordance with the partnership agreement, Crestwood Midstream’s general partner may, from time to time, cause Crestwood Midstream to make cash distributions at the sole discretion of the general partner. During the years ended December 31, 2021, 2020 and 2019, Crestwood Midstream paid cash distributions of $509.7 million, $242.6 million and $235.8 million, which represented net amounts due to Crestwood Midstream related to cash advances to CEQP for its general corporate activities. Non-Controlling Partner Crestwood Niobrara issued $175 million of Series A-2 Preferred Interests to CN Jackalope Holdings LLC (Jackalope Holdings) in conjunction with its equity interest in Jackalope. In April 2019, Crestwood Niobrara issued $235 million in new Series A-3 Preferred Units (collectively with the Series A-2 Preferred Units defined as the Crestwood Niobrara Preferred Units) to Jackalope Holdings in conjunction with Crestwood Niobrara’s acquisition of the remaining 50% equity interest in Jackalope from Williams. In connection with the issuance of the Series A-3 Preferred Units, we entered into a Third Amended and Restated Limited Liability Company Agreement (Crestwood Niobrara Amended Agreement) with Jackalope Holdings, pursuant to which we serve as managing member of Crestwood Niobrara. The Crestwood Niobrara Amended Agreement modified certain provisions under the previous limited liability company agreement related to the conversion and redemption of the Series A-2 Preferred Units, as follows: • The Crestwood Niobrara Preferred Units are convertible by the preferred interest holder starting on January 1, 2021 into Crestwood Niobrara common units. The preferred interest holder has the option to contribute additional capital to Crestwood Niobrara to increase their common ownership percentage in Crestwood Niobrara to 50% upon the conversion. • The Crestwood Niobrara Preferred Units are redeemable by the preferred interest holder starting on December 31, 2023 for an amount equal to the Liquidation Preference (as defined in the Crestwood Niobrara Amended Agreement). If redemption is elected by the preferred interest holder, we have the option to elect to give consideration equal to the Liquidation Preference in either (i) unregistered CEQP common units (subject to a Registration Rights Agreement) with a total value of up to $100 million and/or cash; or (ii) proceeds from a full liquidation of Crestwood Niobrara’s assets and unregistered CEQP common units (subject to a Registration Rights Agreement). • The Crestwood Niobrara Preferred Units are redeemable by us starting on January 1, 2023 for either (i) unregistered CEQP common units (subject to a Registration Rights Agreement) with a total value of up to $100 million and/or cash; or (ii) proceeds from a full liquidation of Crestwood Niobrara’s assets and registered CEQP common units (subject to a Registration Rights Agreement). As a result of the modification of the conversion and redemption provisions of the Crestwood Niobrara Preferred Units, we continue to consolidate Crestwood Niobrara and have reflected the preferred interests as a non-controlling interest in subsidiary apart from partners’ capital (i.e., temporary equity) on our consolidated balance sheets at December 31, 2021 and 2020. We adjust the carrying amount of the non-controlling interest to its redemption value each period through net income attributable to non-controlling partner. The following table shows the change in the interest of our non-controlling partner in subsidiary at December 31, 2021, 2020 and 2019 (in millions) : Balance at December 31, 2018 $ — Reclassification of Series A-2 Preferred Units 178.8 Issuance of Series A-3 Preferred Units 235.0 Distributions to non-controlling partner (18.4) Net income attributable to non-controlling partner 30.8 Balance at December 31, 2019 426.2 Contributions from non-controlling partner 2.8 Distributions to non-controlling partner (37.1) Net income attributable to non-controlling partner 40.8 Balance at December 31, 2020 432.7 Contributions from non-controlling partner 1.0 Distributions to non-controlling partner (40.2) Net income attributable to non-controlling partner 41.1 Balance at December 31, 2021 $ 434.6

Equity Plans

Equity Plans	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Equity Plan	Equity Plans Long-term incentive awards are granted under the Crestwood LTIP in order to align the economic interests of key employees and directors with those of CEQP’s common unitholders and to provide an incentive for continuous employment. Long-term incentive compensation consist of grants of restricted, phantom and performance units which vest based upon continued service. As of December 31, 2021 and 2020, we had total unamortized compensation expense of approximately $33.2 million and $29.7 million related to restricted, phantom, and performance units, which will be amortized during the next three years (or sooner in certain cases, which generally represents the original vesting period of these instruments), except for grants to non-employee directors of our general partner, which vest over one year. We recognized compensation expense of approximately $39.5 million, $35.1 million and $45.1 million under the Crestwood LTIP during the years ended December 31, 2021, 2020 and 2019, which is included in general and administrative expenses on our consolidated statements of operations. During the years ended December 31, 2021 and 2020, compensation expense includes approximately $4.4 million and $1.4 million related to equity awards under the Crestwood LTIP that was included in accrued expenses and other liabilities on our consolidated balance sheets. As of February 18, 2022, we had 2,530,862 units available for issuance under the Crestwood LTIP. Restricted Units . The Crestwood LTIP permits grants of restricted units that are designed to provide an incentive for continuous employment to certain key employees. Restricted units vest over a three-year period following the grant date or, if earlier, upon change of control of Crestwood Equity’s general partner or due to death or disability of the employee. Phantom Units. The Crestwood LTIP permits grants of phantom units that entitle the holder to receive upon vesting one CEQP common unit pursuant to the Crestwood LTIP and the Crestwood Equity Phantom Unit Agreement. The Crestwood Equity Phantom Unit Agreement provides for vesting to occur at the end of three years following the grant date or, if earlier, upon the named executive officer’s termination without cause or due to death or disability or the named executive officer’s resignation for employee cause (each, as defined in the Crestwood Equity Phantom Unit Agreement). In addition, the Crestwood Equity Phantom Unit Agreement provides for distribution equivalent rights with respect to each phantom unit which are paid in additional phantom units and settled in common units upon vesting of the underlying phantom units. Performance Units. The Crestwood LTIP permits grants of performance units that are designed to provide an incentive for continuous employment to certain key employees. The vesting of performance units is subject to the attainment of certain performance and market goals over a three-year period and entitle a participant to receive common units of Crestwood Equity without payment of an exercise price upon vesting. The number of units issued are based on a performance multiplier ranging between 50% and 200%, determined based on the actual performance in the third year of the performance period compared to pre-established performance goals. The performance goals are based on achieving a specified level of distributable cash flow per unit, Adjusted EBITDA, return on capital invested, and three-year relative total shareholder return. The following table summarizes information regarding restricted, phantom and performance unit activity during the years ended December 31, 2021, 2020 and 2019. Units Weighted-Average Grant Date Fair Value Unvested - January 1, 2019 2,187,970 $ 24.78 Granted - restricted units 988,096 $ 31.48 Granted - phantom units 7,164 $ 29.03 Granted - performance units 238,263 $ 34.21 Vested - restricted units (985,751) $ 23.39 Vested - performance units (32,246) $ 34.21 Forfeited - restricted units (47,547) $ 27.85 Unvested - December 31, 2019 2,355,949 $ 28.94 Granted - restricted units 1,569,451 $ 25.42 Granted - phantom units 17,726 $ 28.48 Granted - performance units 715,674 $ 28.46 Vested - restricted units (906,275) $ 28.75 Vested - phantom units (2,118) $ 26.63 Vested - performance units (846,306) $ 29.85 Forfeited - restricted units (149,001) $ 28.24 Forfeited - phantom units (14,157) $ 27.91 Forfeited - performance units (17,087) $ 27.35 Unvested - December 31, 2020 2,723,856 $ 26.62 Granted - restricted units 1,399,781 $ 20.51 Granted - phantom units 5,795 $ 18.88 Granted - performance units 71,286 $ 25.60 Vested - restricted units (1,148,928) $ 27.65 Vested - phantom units (2,117) $ 26.63 Forfeited - restricted units (48,565) $ 21.67 Unvested - December 31, 2021 3,001,108 $ 23.42 Under the Crestwood LTIP, participants who have been granted restricted units and/or performance units may elect to have us withhold common units to satisfy minimum statutory tax withholding obligations arising in connection with the vesting of non-vested common units. Any such common units withheld are returned to the Crestwood LTIP on the applicable vesting dates, which correspond to the times at which income is recognized by the employee. When we withhold these common units, we are required to remit to the appropriate taxing authorities the fair value of the units withheld as of the vesting date. The number of units withheld is determined based on the closing price per common unit as reported on the NYSE on such dates. During the years ended December 31, 2021, 2020, and 2019, we withheld 423,330, 581,608 and 336,548 common units to satisfy employee tax withholding obligations for the restricted and performance units. Employee Unit Purchase Plan In August 2018, the board of directors of our general partner approved an employee unit purchase plan under which employees of the general partner may purchase our common units through payroll deductions up to a maximum of 10% of the employees’ eligible compensation, not to exceed $25,000 for any calendar year. Under the plan, we anticipate purchasing our common units on the open market for the benefit of participating employees based on their payroll deductions. In addition, we may match up to 10% of participating employees’ payroll deductions to purchase additional Crestwood common units for participating employees. The board of directors of our general partner authorized 1,500,000 common units (subject to adjustment as provided in the employee unit purchase plan) to be available for purchase. During the years ended December 31, 2021, 2020 and 2019, 9,932, 29,784 and 6,341 common units were purchased under the plan.

Earnings Per Limited Partner Un

Earnings Per Limited Partner Unit	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
Earnings Per Limited Partner Unit	Earnings Per Limited Partner Unit Prior to the Crestwood Holdings transactions, we calculated basic net income per limited partner unit using the two-class method. Our income (loss) was allocated to our common units and other participating securities (i.e., subordinated units) based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in income (loss) or excess distributions over income (loss). The dilutive effect of the unit-based compensation performance units is calculated using the treasury stock method which considers the impact to net income or loss attributable to Crestwood Equity Partners and limited partner units from the potential issuance of limited partner units. The dilutive effect of the preferred units and Crestwood Niobrara preferred units are calculated using the if-converted method which assumes units are converted at the beginning of the period (beginning with their respective issuance date), and the resulting common units are included in the denominator of the diluted net income per common unit calculation for the period being presented. Distributions declared in the period and undeclared distributions that accumulated during the period are added back to the numerator for purposes of the if-converted calculation. We exclude potentially dilutive securities from the determination of diluted earnings per unit (as well as their related income statement impacts) when their impact is anti-dilutive. The following table summarizes information regarding the weighted-average of common units excluded during the years ended December 31, 2021, 2020 and 2019 (in millions) : Year Ended December 31, 2021 2020 2019 Preferred units (1) 7.1 7.1 7.1 Crestwood Niobrara’s preferred units (1) 4.2 5.7 — Unit-based compensation performance units (2) 0.2 0.1 — Subordinated units (3) 0.1 0.4 — (1) See Note 12 for additional information regarding the potential conversion of our preferred units and Crestwood Niobrara’s preferred units to common units. (2) For a description of our unit-based compensation performance units, see Note 13. (3) In conjunction with the Crestwood Holdings Transactions, in March 2021, CEQP retired the subordinated units. For additional information regarding the retirement of the subordinated units, see Note 12. The following table shows net income (loss) and weighted-average limited partner units used in computing basic and diluted net income (loss) per limited partner unit for the years ended December 31, 2021, 2020 and 2019 (in millions, except per unit data) : Year Ended December 31, 2021 2020 2019 Common unitholders’ interest in net income (loss) $ (138.6) $ (116.2) $ 223.6 Dilutive effect of net income attributable to subordinated units — — 1.4 Diluted net income (loss) $ (138.6) $ (116.2) $ 225.0 Weighted-average limited partners’ units outstanding - basic 65.6 73.2 71.8 Dilutive effect of Crestwood Niobrara preferred units — — 4.3 Dilutive effect of stock-based compensation performance units — — 0.4 Dilutive effect of subordinated units — — 0.4 Weighted-average limited partners’ units outstanding - diluted 65.6 73.2 76.9 Net income (loss) per limited partner unit: Basic $ (2.11) $ (1.59) $ 3.11 Diluted $ (2.11) $ (1.59) $ 2.93

Employee Benefit Plan

Employee Benefit Plan	12 Months Ended
	Dec. 31, 2021
Postemployment Benefits [Abstract]
Employee Benefit Plans	Employee Benefit PlanA 401(k) plan is available to all of our employees after meeting certain requirements. The plan permits employees to make contributions of up to 90% of their salary, subject to statutory limits, which was $19,500 in 2021, $19,500 in 2020 and $19,000 in 2019. We match 100% of participants’ basic contributions up to 6% of eligible compensation. Employees may participate in the plans immediately and certain employees are not eligible for matching contributions until after a 90-day waiting period. During the years ended December 31, 2021, 2020 and 2019, aggregate matching contributions made by us were $4.0 million, $4.2 million and $4.7 million.

Segments

Segments	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Segments	Segments In conjunction with the divestiture of our Stagecoach Gas equity method investment as discussed in Note 6 and the definitive merger agreement we entered into with Oasis Midstream as discussed in Note 20, we modified our segments as of December 31, 2021 and, as a result, our financial statements reflect three operating and reporting segments: (i) gathering and processing north operations (includes our Arrow and Jackalope operations); (ii) gathering and processing south operations (includes our Marcellus and Barnett operations and our Crestwood Permian Basin Holdings LLC equity method investment); and (iii) storage and logistics operations (includes our crude oil, NGL and natural gas storage and logistics operations, and our Tres Holdings and PRBIC equity method investments). Our gathering and processing north and gathering and processing south segments were historically combined into one segment, and our storage and logistics segment was historically separated into a storage and transportation segment and a marketing, supply and logistics segment. The financial results of our operations described above are now reflected in the new respective segments for all periods presented. Our corporate operations include all general and administrative expenses that are not allocated to our reportable segments. Below is a description of our operating and reporting segments. • Gathering and Processing North . Our gathering and processing north operations provide natural gas, crude oil and produced water gathering, compression, treating, processing and disposal services to producers in the Williston Basin and Powder River Basin. • Gathering and Processing South . Our gathering and processing south operations provide natural gas gathering, compression, treating and processing and produced water gathering and disposal services to producers in the Marcellus, Barnett and Delaware basins. • Storage and Logistics . Our storage and logistics operations provide NGL, crude oil and natural gas storage, terminal, marketing and transportation (including rail, truck and pipeline) services to producers, refiners, marketers, utilities and other customers. We assess the performance of our operating segments based on EBITDA, which is defined as income before income taxes, plus debt-related costs (net interest and debt expense and gain (loss) on modification/extinguishment of debt) and depreciation, amortization and accretion expense. Below is a reconciliation of CEQP’s and CMLP’s net income (loss) to EBITDA ( in millions ): CEQP CMLP Year Ended December 31, Year Ended December 31, 2021 2020 2019 2021 2020 2019 Net income (loss) $ (37.4) $ (15.3) $ 319.9 $ (44.0) $ (23.4) $ 310.6 Add: Interest and debt expense, net 132.1 133.6 115.4 132.1 133.6 115.4 (Gain) loss on modification/extinguishment of debt 7.5 (0.1) — 7.5 (0.1) — Provision (benefit) for income taxes 0.2 0.4 0.3 0.1 (0.1) 0.3 Depreciation, amortization and accretion 244.2 237.4 195.8 258.4 251.5 209.9 EBITDA $ 346.6 $ 356.0 $ 631.4 $ 354.1 $ 361.5 $ 636.2 The following tables summarize CEQP’s and CMLP’s reportable segment data for the years ended December 31, 2021, 2020 and 2019 ( in millions ). Intersegment revenues included in the following tables are accounted for as arms-length transactions that apply our revenue recognition policy described in Note 2. Included in earnings (loss) from unconsolidated affiliates, net reflected in the tables below was approximately $187.4 million, $42.9 million and $42.1 million of our proportionate share of interest expense, depreciation and amortization expense, goodwill impairments and gains (losses) on long-lived assets, net recorded by our equity investments for the years ended December 31, 2021, 2020 and 2019, respectively. Segment EBITDA Information Year Ended December 31, 2021 Gathering and Processing North Gathering and Processing South Storage and Logistics Corporate Total Crestwood Midstream Revenues $ 574.7 $ 105.9 $ 3,888.4 $ — $ 4,569.0 Intersegment revenues 459.3 — (459.3) — — Costs of product/services sold 553.2 0.9 3,289.8 — 3,843.9 Operations and maintenance expense 51.1 22.9 47.0 — 121.0 General and administrative expense — — — 90.2 90.2 Gain (loss) on long-lived assets, net 0.4 (40.6) 0.7 0.1 (39.4) Earnings (loss) from unconsolidated affiliates, net — 9.6 (130.0) — (120.4) Crestwood Midstream EBITDA $ 430.1 $ 51.1 $ (37.0) $ (90.1) $ 354.1 Crestwood Equity General and administrative expense — — — 7.4 7.4 Loss on long-lived assets, net — — — (0.2) (0.2) Other income — — — 0.1 0.1 Crestwood Equity EBITDA $ 430.1 $ 51.1 $ (37.0) $ (97.6) $ 346.6 Year Ended December 31, 2020 Gathering and Processing North Gathering and Processing South Storage and Logistics Corporate Total Crestwood Midstream Revenues $ 510.4 $ 121.0 $ 1,622.9 $ — $ 2,254.3 Intersegment revenues 160.5 (0.7) (159.8) — — Costs of product/services sold 261.0 0.5 1,339.0 — 1,600.5 Operations and maintenance expense 55.7 29.2 46.9 — 131.8 General and administrative expense — — — 86.7 86.7 Gain (loss) on long-lived assets, net (3.8) (20.0) (2.4) 0.2 (26.0) Goodwill impairment (80.3) — — — (80.3) Earnings (loss) from unconsolidated affiliates, net — (1.0) 33.5 — 32.5 Crestwood Midstream EBITDA $ 270.1 $ 69.6 $ 108.3 $ (86.5) $ 361.5 Crestwood Equity General and administrative expense — — — 4.8 4.8 Other expense — — — (0.7) (0.7) Crestwood Equity EBITDA $ 270.1 $ 69.6 $ 108.3 $ (92.0) $ 356.0 Year Ended December 31, 2019 Gathering and Processing North Gathering and Processing South Storage and Logistics Corporate Total Crestwood Midstream Revenues $ 686.9 $ 148.9 $ 2,346.1 $ — $ 3,181.9 Intersegment revenues 174.9 0.1 (175.0) — — Costs of product/services sold 524.0 2.1 2,018.8 — 2,544.9 Operations and maintenance expense 60.8 37.9 40.1 — 138.8 General and administrative expense — — — 98.2 98.2 Gain (loss) on long-lived assets, net (4.2) (2.0) (0.2) 0.2 (6.2) Gain on acquisition 209.4 — — — 209.4 Earnings (loss) from unconsolidated affiliates, net 3.7 (5.8) 34.9 — 32.8 Other income, net — — — 0.2 0.2 Crestwood Midstream EBITDA $ 485.9 $ 101.2 $ 146.9 $ (97.8) $ 636.2 Crestwood Equity General and administrative expense — — — 5.2 5.2 Other income — — — 0.4 0.4 Crestwood Equity EBITDA $ 485.9 $ 101.2 $ 146.9 $ (102.6) $ 631.4 Other Segment Information CEQP CMLP Year Ended December 31, Year Ended December 31, 2021 2020 2021 2020 Total Assets Gathering and Processing North $ 2,408.0 $ 2,480.4 $ 2,408.0 $ 2,480.4 Gathering and Processing South 886.5 984.2 1,017.4 1,129.3 Storage and Logistics 1,125.1 1,749.6 1,125.1 1,749.6 Corporate 26.1 29.5 20.7 26.2 Total assets $ 4,445.7 $ 5,243.7 $ 4,571.2 $ 5,385.5 Year Ended December 31, 2021 2020 2019 Purchases of property, plant and equipment Crestwood Midstream Gathering and Processing North $ 66.1 $ 156.5 $ 434.4 Gathering and Processing South 7.9 3.2 13.3 Storage and Logistics 6.6 7.5 5.9 Corporate 0.7 1.1 1.9 Total Crestwood Midstream purchases of property, plant and equipment $ 81.3 $ 168.3 $ 455.5 Crestwood Equity Corporate 1.9 — — Total Crestwood Equity purchases of property, plant and equipment $ 83.2 $ 168.3 $ 455.5 Major Customers No customer accounted for 10% or more of our total consolidated revenues for the years ended December 31, 2021 and 2020 at CEQP or CMLP. For the year ended December 31, 2019, revenues from British Petroleum and its affiliates of approximately

Revenues

Revenues	12 Months Ended
	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer [Text Block]	Revenues Contract Assets and Contract Liabilities Our contract assets and contract liabilities are reported in a net position on a contract-by-contract basis at the end of each reporting period. Our receivables related to our revenue contracts accounted for under Topic 606 totaled $331.0 million and $219.9 million at December 31, 2021 and 2020, and are included in accounts receivable on our consolidated balance sheets. Our contract assets are included in other non-current assets on our consolidated balance sheets. Our contract liabilities primarily consist of current and non-current deferred revenues. On our consolidated balance sheets, our current deferred revenues are included in accrued expenses and other liabilities and our non-current deferred revenues are included in other long-term liabilities. The majority of revenues associated with our deferred revenues is expected to be recognized as the performance obligations under the related contracts are satisfied over the next 15 years. The following table summarizes our contract assets and contract liabilities (in millions) : December 31, 2021 2020 Contract assets (non-current) $ 1.3 $ 1.0 Contract liabilities (current) (1) $ 10.7 $ 10.3 Contract liabilities (non-current) (1) $ 187.1 $ 172.2 (1) During the year ended December 31, 2021, we recognized revenues of approximately $14.0 million that were previously included in contract liabilities at December 31, 2020. The remaining change in our contract liabilities during the year ended December 31, 2021 related to capital reimbursements associated with our revenue contracts and revenue deferrals associated with our contracts with increasing (decreasing) rates. The following table summarizes the transaction price allocated to our remaining performance obligations under certain contracts that have not been recognized as of December 31, 2021 (in millions) : 2022 $ 72.7 2023 52.6 2024 31.7 2025 0.1 Total $ 157.1 Our remaining performance obligations presented in the table above exclude estimates of variable rate escalation clauses in our contracts with customers, and is generally limited to fixed-fee and percentage-of-proceeds service contracts which have fixed pricing and minimum volume terms and conditions. Our remaining performance obligations generally exclude, based on the following practical expedients that we elected to apply, disclosures for (i) variable consideration allocated to a wholly-unsatisfied promise to transfer a distinct service that forms part of the identified single performance obligation; (ii) unsatisfied performance obligations where the contract term is one year or less; and (iii) contracts for which we recognize revenues as amounts are invoiced. Disaggregation of Revenues The following tables summarize our revenues from contracts with customers disaggregated by type of product/service sold and by commodity type for each of our segments for the years ended December 31, 2021, 2020 and 2019 ( in millions ). In addition, the revenues from contracts with customers are presented in the three operating and reporting segments that are further discussed in Note 16 for all periods presented. We believe this summary best depicts how the nature, amount, timing and uncertainty of our revenues and cash flows are affected by economic factors. Our non- Topic 606 revenues presented in the tables below primarily represent revenues related to our commodity-based derivatives. Year Ended December 31, 2021 Gathering and Processing North Gathering and Processing South Storage and Logistics Intersegment Elimination Total Topic 606 revenues Gathering Natural gas $ 56.3 $ 83.2 $ — $ — $ 139.5 Crude oil 73.1 — — — 73.1 Water 94.0 — — — 94.0 Processing Natural gas 24.4 5.0 — — 29.4 Compression Natural gas — 17.1 — — 17.1 Storage Crude oil 0.3 — 0.5 (0.3) 0.5 NGLs — — 11.5 — 11.5 Pipeline Crude oil — — 2.6 — 2.6 NGLs — — 0.2 — 0.2 Transportation Crude oil 2.7 — — (0.1) 2.6 NGLs — — 17.3 — 17.3 Rail Loading Crude oil — — 4.6 — 4.6 Product Sales Natural gas 171.4 0.6 326.2 (171.1) 327.1 Crude oil 401.5 — 1,237.7 (82.6) 1,556.6 NGLs 209.4 — 1,796.6 (205.2) 1,800.8 Other — — 1.7 — 1.7 Total Topic 606 revenues 1,033.1 105.9 3,398.9 (459.3) 4,078.6 Non-Topic 606 revenues 0.9 — 489.5 — 490.4 Total revenues $ 1,034.0 $ 105.9 $ 3,888.4 $ (459.3) $ 4,569.0 Year Ended December 31, 2020 Gathering and Processing North Gathering and Processing South Storage and Logistics Intersegment Elimination Total Topic 606 revenues Gathering Natural gas $ 53.4 $ 87.2 $ — $ — $ 140.6 Crude oil 95.3 — — — 95.3 Water 92.6 — — — 92.6 Processing Natural gas 22.4 9.5 — — 31.9 Compression Natural gas — 23.9 — — 23.9 Storage Crude oil 1.1 — 1.9 (0.3) 2.7 NGLs — — 13.1 — 13.1 Pipeline Crude oil — — 4.1 — 4.1 NGLs — — 0.3 — 0.3 Transportation Crude oil 6.2 — 1.9 (0.1) 8.0 NGLs — — 10.9 — 10.9 Rail Loading Crude oil — — 7.4 — 7.4 Product Sales Natural gas 53.7 (0.3) 90.9 (52.8) 91.5 Crude oil 292.2 — 660.7 (53.0) 899.9 NGLs 54.0 — 614.2 (53.6) 614.6 Other — — 1.5 — 1.5 Total Topic 606 revenues 670.9 120.3 1,406.9 (159.8) 2,038.3 Non-Topic 606 revenues — — 216.0 — 216.0 Total revenues 670.9 120.3 1,622.9 (159.8) 2,254.3 Year Ended December 31, 2019 Gathering and Processing North Gathering and Processing South Storage and Logistics Intersegment Elimination Total Topic 606 revenues Gathering Natural gas $ 51.2 $ 112.0 $ — $ — $ 163.2 Crude oil 75.0 — — — 75.0 Water 79.6 — — — 79.6 Processing Natural gas 18.9 10.0 — — 28.9 NGLs — — — — — Compression Natural gas — 24.9 — — 24.9 Storage Crude oil 1.9 — 3.5 (0.4) 5.0 NGLs — — 6.3 — 6.3 Pipeline Crude oil — — 5.2 — 5.2 Transportation Crude oil 7.0 — 5.8 (0.1) 12.7 NGLs — — 11.7 — 11.7 Water — — 0.2 — 0.2 Rail Loading Crude oil — — 11.0 — 11.0 Product Sales Natural gas 55.6 1.2 72.3 (33.4) 95.7 Crude oil 532.1 — 1,315.6 (121.1) 1,726.6 NGLs 40.5 0.9 659.3 (20.0) 680.7 Other — — 1.9 — 1.9 Total Topic 606 revenues 861.8 149.0 2,092.8 (175.0) 2,928.6 Non-Topic 606 revenues — — 253.3 — 253.3 Total revenues $ 861.8 $ 149.0 $ 2,346.1 $ (175.0) $ 3,181.9

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The (provision) benefit for income taxes for the years ended December 31, 2021, 2020, and 2019 consisted of the following (in millions) : CEQP CMLP Year Ended December 31, Year Ended December 31, 2021 2020 2019 2021 2020 2019 Current: Federal $ (0.4) $ (0.2) $ (0.1) $ — $ 0.1 $ 0.1 State (0.2) (0.1) (0.2) (0.1) — (0.2) Total current (0.6) (0.3) (0.3) (0.1) 0.1 (0.1) Deferred: Federal 0.3 (0.1) 0.1 — — — State 0.1 — (0.1) — — (0.2) Total deferred 0.4 (0.1) — — — (0.2) (Provision) benefit for income taxes $ (0.2) $ (0.4) $ (0.3) $ (0.1) $ 0.1 $ (0.3) The effective rate differs from the statutory rate for the years ended December 31, 2021, 2020 and 2019, primarily due to the partnerships not being treated as a corporation for federal income tax purposes as discussed in Note 2. Deferred income taxes related to the operations of CEQP’s wholly-owned taxable subsidiaries, IPCH Acquisition Corp. and Crestwood Gas Services GP LLC, and the impact of Texas Margin tax on our operations, and reflects the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. Components of our deferred income taxes at December 31, 2021 and 2020 are as follows (in millions). CEQP CMLP December 31, December 31, 2021 2020 2021 2020 Total deferred tax asset (1) $ 0.2 $ 0.2 $ — $ — Total deferred tax liability (1) (2.5) (2.9) (0.8) (0.7) Net deferred tax liability $ (2.3) $ (2.7) $ (0.8) $ (0.7) (1) Relates to the basis difference in the stock of a company. Uncertain Tax Positions. We evaluate the uncertainty in tax positions taken or expected to be taken in the course of preparing our consolidated financial statements to determine whether the tax positions are more likely than not of being sustained by the applicable tax authority. Such tax positions, if any, would be recorded as a tax benefit or expense in the current year. We believe that there were no uncertain tax positions that would impact our results of operations for the years ended December 31, 2021, 2020 and 2019 and that no provision for income tax was required for these consolidated financial statements. However, our conclusions regarding the evaluation of uncertain tax positions are subject to review and may change based on factors including, but not limited to, ongoing analyses of tax laws, regulations and interpretations thereof.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2021
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions We enter into transactions with our affiliates within the ordinary course of business, including product purchases, marketing services and various operating agreements, including operating leases. We also enter into transactions with our affiliates related to services provided on our expansion projects. Prior to August 2021, Crestwood Holdings indirectly owned our general partner and the affiliates of Crestwood Holdings and its owners were considered CEQP’s and CMLP’s related parties. With the completion of the Crestwood Holdings Transactions in August 2021, Crestwood Holdings and its affiliates are no longer considered related parties of CEQP and CMLP. During the years ended December 31, 2021, 2020, 2019 and we paid approximately $0.6 million, $3.5 million, and $9.9 million of capital expenditures to Applied Consultants, Inc., an affiliate of Crestwood Holdings. Below is a discussion of certain of our related party services and agreements. Shared Services. CMLP shares common management, general and administrative and overhead costs with CEQP, and as such, CMLP allocates a portion of its costs to CEQP. CEQP grants long-term incentive awards under the Crestwood LTIP as discussed in Note 13 and, as such, CEQP allocates certain of its unit-based compensation costs to CMLP. Prior to the Crestwood Holdings Transactions as discussed in Note 1, Crestwood Holdings allocated its unit-based compensation charges to CEQP and CMLP. Stagecoach Gas Management Agreement. Prior to the sale of our equity interest in Stagecoach Gas as further discussed in Note 6, Crestwood Midstream Operations, LLC (Crestwood Midstream Operations), our wholly-owned subsidiary, provided management and operating services to Stagecoach Gas under a management agreement pursuant to which we operated and maintained Stagecoach Gas’s facilities. Reimbursements received from Stagecoach Gas under this agreement were reflected as a reduction of operations and maintenance expenses in our consolidated statements of operations. Tres Holdings Operating Agreement. CMLP Tres Manager, LLC, a consolidated subsidiary of Crestwood Midstream, entered into an operating agreement with Tres Holdings, pursuant to which we operate and maintain their facilities as well as provide certain administrative and other general services identified in the agreement. Under the operating agreement, Tres Holdings reimburses us for all costs incurred on its behalf. These reimbursements are reflected as a reduction of operations and maintenance expenses in our consolidated statements of operations. Crestwood Permian Operating Agreement. Crestwood Midstream Operations entered into an operating agreement with Crestwood Permian, pursuant to which we provide operating services for Crestwood Permian’s facilities, as well as certain administrative and other general services identified in the agreement. Under the operating agreement, Crestwood Permian reimburses us for all costs incurred on its behalf. These reimbursements are reflected as a reduction of operations and maintenance expenses in our consolidated statements of operations. Jackalope Marketing Services Agreement. Prior to the acquisition of the remaining interest in Jackalope as further discussed in Note 3, Crestwood Niobrara provided marketing services to Jackalope as well as certain administrative and other general services identified under a marketing services agreement. Under this marketing services agreement, Jackalope reimbursed us for all costs incurred on its behalf. These reimbursements are reflected as a reduction of operations and maintenance expenses in our consolidated statements of operations. The following table shows transactions with our affiliates which are reflected in our consolidated statements of operations for the years December 31, 2021, 2020 and 2019 ( in millions ): Year Ended December 31, 2021 2020 2019 Revenues at CEQP and CMLP (1) $ 27.2 $ 27.8 $ 2.9 Costs of product/services sold at CEQP and CMLP (2) $ 136.8 $ 21.0 $ 45.4 Operations and maintenance expenses at CEQP and CMLP charged to our unconsolidated affiliates (3) $ 22.2 $ 21.8 $ 25.9 General and administrative expenses charged by CEQP to CMLP, net (4) $ 35.5 $ 31.1 $ 41.4 General and administrative expenses at CEQP charged to (from) Crestwood Holdings, net (5) $ 4.8 $ 6.5 $ (0.6) (1) Includes (i) $26.2 million, $27.8 million and $1.0 million during the years ended December 31, 2021, 2020 and 2019 related to the sale of NGLs to a subsidiary of Crestwood Permian; (ii) $1.0 million during the year ended December 31, 2021 related to a compressor lease with a subsidiary of Crestwood Permian (iii) $1.2 million during the year ended December 31, 2019 related to the sale of natural gas to a subsidiary of Stagecoach Gas: and (iv) $0.7 million during the year ended December 31, 2019 related to the sale of NGLs to our affiliate, Westlake Chemical Corporation. (2) Includes (i) $110.7 million, $20.0 million and $19.0 million during the years ended December 31, 2021, 2020 and 2019 related to purchases of natural gas and NGLs from a subsidiary of Crestwood Permian; (ii) $11.6 million and $0.6 million during the years ended December 31, 2021 and 2020 related to purchases of natural gas from a subsidiary of Tres Holdings; (iii) $14.5 million, $0.4 million and $23.9 million during the years ended December 31, 2021, 2020 and 2019 related to purchases of NGLs from Ascent Resources - Utica, LLC (Ascent); (iv) $0.2 million during the year ended December 31, 2019 related to purchases of NGLs from Blue Racer Midstream, LLC (Blue Racer); and (v) $2.3 million during the year ended December 31, 2019 related to purchases of natural gas from a subsidiary of Stagecoach Gas. Ascent and Blue Racer are affiliates of Crestwood Holdings for the respective periods presented. (3) We have operating agreements with certain of our unconsolidated affiliates pursuant to which we charge them operations and maintenance expenses in accordance with their respective agreements described above. During the year ended December 31, 2021, we charged $3.4 million to Stagecoach Gas, $4.9 million to Tres Holdings, and $13.9 million to Crestwood Permian under these agreements. During the year ended December 31, 2020, we charged $6.6 million to Stagecoach Gas, $4.1 million to Tres Holdings and $11.1 million to Crestwood Permian under these agreements. During the year ended December 31, 2019, we charged $7.5 million to Stagecoach Gas, $4.4 million to Tres Holdings, $13.5 million to Crestwood Permian and $0.5 million to Jackalope under these agreements. (4) Includes $39.5 million, $35.1 million and $45.1 million of unit-based compensation charges allocated from CEQP to CMLP during the years ended December 31, 2021, 2020 and 2019. In addition, includes $4.0 million, $4.0 million and $3.7 million of CMLP’s general and administrative costs allocated to CEQP during the years ended December 31, 2021, 2020 and 2019. (5) Includes a $4.6 million and $4.4 million reduction of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the years ended December 31, 2021 and 2020 and $1.9 million of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the year ended December 31, 2019. CEQP allocates a portion of its general and administrative costs to Crestwood Holdings and during the years ended December 31, 2021, 2020 and 2019, CEQP allocated $0.2 million, $2.1 million and $1.3 million of its general and administrative costs to Crestwood Holdings. The following table shows accounts receivable and accounts payable from our affiliates as of December 31, 2021 and 2020 ( in millions ): December 31, 2021 2020 Accounts receivable at CEQP and CMLP $ 8.2 $ 2.5 Accounts payable at CEQP $ 12.0 $ 7.5 Accounts payable at CMLP $ 12.0 $ 5.0

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2021
Subsequent Events [Abstract]
Subsequent Events	Subsequent Event On October 25, 2021, we entered into a merger agreement to acquire Oasis Midstream in an equity and cash transaction (the Merger). Oasis Midstream is a master limited partnership which operates a diversified portfolio of midstream assets in located in the Williston and Delaware Basins and its operations include natural gas services (gathering, compression, processing and gas lift supply) crude oil services (gathering, terminalling and transportation) and water services (gathering and disposal of produced and flowback water and freshwater distribution). On February 1, 2022, we completed the merger with Oasis Midstream, which was valued at approximately $1.8 billion. Pursuant to the merger agreement, Oasis Petroleum Inc. (Oasis Petroleum) received $150 million in cash plus approximately 21.0 million newly issued CEQP common units in exchange for its 33.8 million common units held in Oasis Midstream. In addition, Oasis Midstream’s public unitholders received approximately 12.9 million newly issued CEQP common units in exchange for the approximately 14.8 million Oasis Midstream common units held by them. Additionally, under the merger agreement Oasis Petroleum received a $10 million cash payment for its ownership of the general partner of Oasis Midstream. . We will account for the Merger as a business combination using the acquisition method of accounting. We are completing our analysis of the purchase price consideration and estimating the fair value of assets acquired and liabilities assumed in connection with the Merger, which is primarily comprised of property, plant and equipment, intangible assets, goodwill and other long-term debt, however, due to the timing of the Merger, we are unable to provide amounts recognized as of the acquisition date for these major classes of assets and liabilities acquired. During the year ended December 31, 2021, we recognized approximately $2.9 million of transaction costs related to the Merger, which are included in general and administrative expenses in our consolidated statements of operations.

Schedule I - Crestwood Equity P

Schedule I - Crestwood Equity Partners LP - Parent Only	12 Months Ended
	Dec. 31, 2021
Condensed Financial Information Disclosure [Abstract]
Schedule I - Crestwood Equity Partners LP - Parent Only	Schedule I Crestwood Equity Partners LP Parent Only Condensed Balance Sheets (in millions) December 31, 2021 2020 Assets Current assets: Cash $ 0.2 $ 0.2 Prepaid expenses and other current assets 0.4 — Total current assets 0.6 0.2 Property, plant and equipment, net 2.5 0.9 Investments in subsidiaries 1,100.1 1,655.7 Other assets 2.1 2.1 Total assets $ 1,105.3 $ 1,658.9 Liabilities and partners’ capital Current liabilities: Accounts payable $ 0.1 $ 0.1 Accrued expenses 1.0 1.9 Total current liabilities 1.1 2.0 Other long-term liabilities 4.6 1.5 Total partners’ capital 1,099.6 1,655.4 Total liabilities and partners’ capital $ 1,105.3 $ 1,658.9 See accompanying notes. Schedule I Crestwood Equity Partners LP Parent Only Condensed Statements of Comprehensive Income (in millions) Year Ended December 31, 2021 2020 2019 Revenues $ — $ — $ — Expenses 7.7 4.9 5.3 Operating loss (7.7) (4.9) (5.3) Equity in net income (loss) of subsidiaries (70.9) (50.5) 290.0 Other income (expense), net 0.1 (0.7) 0.4 Net income (loss) attributable to Crestwood Equity Partners LP (78.5) (56.1) 285.1 Other comprehensive income Change in fair value of Suburban Propane Partners, L.P. units — — 0.3 Comprehensive income (loss) attributable to Crestwood Equity Partners LP $ (78.5) $ (56.1) $ 285.4 See accompanying notes. Schedule I Crestwood Equity Partners LP Parent Only Condensed Statements of Cash Flows (in millions) Year Ended December 31, 2021 2020 2019 Cash flows from operating activities $ (5.5) $ (9.4) $ (3.7) Cash flows from investing activities 507.8 242.6 235.8 Cash flows from financing activities: Payments for Crestwood Holdings Transactions (275.6) — — Distributions paid to partners (224.4) (242.8) (232.5) Change in intercompany balances (2.3) 9.6 0.4 Net cash used in financing activities (502.3) (233.2) (232.1) Net change in cash — — — Cash at beginning of period 0.2 0.2 0.2 Cash at end of period $ 0.2 $ 0.2 $ 0.2 See accompanying notes. Schedule I Crestwood Equity Partners LP Parent Only Notes to Condensed Financial Statements Note 1. Basis of Presentation In the parent-only financial statements, our investment in subsidiaries is stated at cost plus equity in undistributed earnings of subsidiaries since the date of acquisition. Our share of net income of our unconsolidated subsidiaries is included in consolidated income using the equity method. The parent-only financial statements should be read in conjunction with our consolidated financial statements. Note 2. Distributions During the years ended December 31, 2021, 2020 and 2019, we received cash distributions from Crestwood Midstream Partners LP of approximately $509.7 million, $242.6 million and $235.8 million.

Schedule II - Crestwood Equity

Schedule II - Crestwood Equity Parnters LP - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2021
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
Schedule II - Crestwood Equity Partners LP - Valuation and Qualifying Accounts	Schedule II Crestwood Equity Partners LP Crestwood Midstream Partners LP Valuation and Qualifying Accounts For the Years Ended December 31, 2021, 2020 and 2019 (in millions) Balance at Charged Other additions (1) Deductions Balance Allowance for doubtful accounts 2021 $ 0.9 $ 0.6 $ — $ (0.9) $ 0.6 2020 $ 0.3 $ 0.5 $ 0.7 $ (0.6) $ 0.9 2019 $ 0.3 $ 0.1 $ — $ (0.1) $ 0.3 (1) Amount represents the cumulative effect of adopting the provisions of Topic 326 on January 1, 2020, which is further discussed in Note 2.

Basis of Presentation and Sum_2

Basis of Presentation and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation We consolidate entities when we have the ability to control or direct the operating and financial decisions of the entity or when we have a significant interest in the entity that gives us the ability to direct the activities that are significant to that entity. The determination to consolidate or apply the equity method of accounting to an entity can also require us to evaluate whether that entity is considered a variable interest entity. This evaluation, along with the determination of our ability to control, direct or exert significant influence over an entity involves the use of judgment. We apply the equity method of accounting where we can exert significant influence over, but do not control or direct the policies, decisions or activities of an entity. We use the cost method of accounting where we are unable to exert significant influence over the entity.
Use of Estimates	Use of Estimates The preparation of our consolidated financial statements in conformity with GAAP requires the use of estimates and assumptions that affect the amounts we report as assets, liabilities, revenues and expenses and our disclosures in these consolidated financial statements. Actual results can differ from those estimates.
Cash	Cash We consider all highly liquid investments with an original maturity of less than three months to be cash.
Accounts Receivable	Accounts Receivable On January 1, 2020, we adopted the provisions of ASU 2016-13, Financial Instruments - Credit Losses (Topic 326) , which provides revised guidance on evaluating accounts and notes receivable and other financial instruments for impairment. We record accounts receivable when products or services are delivered and it is probable that payment will be received for those products or services, and we do not record any interest or penalties on accounts receivable that are past due under the terms of the related arrangement or invoice until those amounts are received. Topic 326
Inventory	InventoryOur inventory, which is stated at the lower of cost or net realizable value and cost is computed predominantly using the average cost method
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment is recorded at is original cost of construction or, upon acquisition, at the fair value of the assets acquired. For assets we construct, we capitalize direct costs, such as labor and materials, and indirect costs, such as overhead and interest. We capitalize major units of property replacements or improvement and expense minor items. Depreciation is computed using the straight-line method over the estimated useful lives of the assets, as follows: Years Gathering systems and pipelines 15 - 20 Facilities and equipment 3 - 25 Buildings, rights-of-way and easements 1 - 40 Office furniture and fixtures 5- 10 Vehicles 5 We evaluate our long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If such events or changes in circumstances are present, a loss is recognized if the carrying value of the asset is in excess of the sum of the undiscounted cash flows expected to result from the use of the asset and its eventual disposition. An impairment loss is measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset, which is typically based on discounted cash flow projections using assumptions as to revenues, costs and discount rates typical of third party market participants, which is a Level 3 fair value measurement. Projected cash flows of our property, plant and equipment are generally based on current and anticipated future market conditions, which require significant judgment to make projections and assumptions about pricing, demand, competition, operating costs, constructions costs, legal and regulatory issues and other factors that may extend many years into the future and are often outside of our control. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates.
Identifiable Intangible Assets	Identifiable Intangible Assets Our identifiable intangible assets consist of customer accounts, trademarks and certain revenue contracts. These intangible assets have arisen primarily from acquisitions. We amortize certain of our revenue contracts based on the projected cash flows associated with these contracts if the projected cash flows are readily determinable, otherwise we amortize our revenue contracts on a straight-line basis. We recognize acquired intangible assets separately if the benefit of the intangible asset is obtained through contractual or other legal rights, or if the intangible asset can be sold, transferred, licensed, rented or exchanged, regardless of the acquirer’s intent to do so. Projected cash flows of our intangible assets are generally based on current and anticipated future market conditions, which require significant judgment to make projections and assumptions about pricing, demand, competition, operating costs, construction costs, legal and regulatory issues and other factors that may extend many years into the future and are often outside of our control. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates.
Goodwill	Goodwill Our goodwill represents the excess of the amount we paid for a business over the fair value of the net identifiable assets acquired. We evaluate goodwill for impairment annually on December 31, and whenever events indicate that it is more likely than not that the fair value of a reporting unit could be less than its carrying amount. This evaluation requires us to compare the fair value of each of our reporting units to its carrying value (including goodwill). If the fair value exceeds the carrying amount, goodwill of the reporting unit is not considered impaired. We estimate the fair value of our reporting units based on a number of factors, including discount rates, projected cash flows and the potential value we would receive if we sold the reporting unit. Estimating projected cash flows requires us to make certain assumptions as it relates to the future operating performance of each of our reporting units (which includes assumptions, among others, about estimating future operating margins and related future growth in those margins, contracting efforts and the cost and timing of facility expansions) and assumptions related to our customers, such as their future capital and operating plans and their financial condition. When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. If the assumptions embodied in the projections prove inaccurate, we could incur a future impairment charge. In addition, the use of the income approach to determine the fair value of our reporting units (see further discussion of the use of the income approach below) could result in a different fair value if we had utilized a market approach, or a combination thereof. Upon acquisition, we are required to record the assets, liabilities and goodwill of a reporting unit at its fair value on the date of acquisition. As a result, any level of decrease in the forecasted cash flows of these businesses or increases in the discount rates utilized to value those businesses from their respective acquisition dates would likely result in the fair value of the reporting unit falling below the carrying value of the reporting unit, and could result in an assessment of whether that reporting unit’s goodwill is impaired.
Lessee, Leases	Leases We enter into leases with third parties for the right to utilize certain office buildings, crude oil railroad cars, vehicles and other operating facilities and equipment. For contracts that extend for a period greater than 12 months, we recognize a right-of-use asset and a corresponding lease liability on our consolidated balance sheet based on the present value of each lease, which is based on the future minimum lease payments and is determined by discounting these payments using our incremental borrowing rate. We recognize operating lease expense on our consolidated statements of operations as either costs of product/services sold, operations and maintenance expenses or general and administrative expenses on a straight-line basis over the lease term. We do not have any material leases where we are considered to be the lessor. Our lease agreements do not contain any material residual value guarantees or material restrictive covenants. We do not have any material revenue contracts that are considered leases.
Investment in Unconsolidated Affiliate	Investments in Unconsolidated AffiliatesEquity method investments in which we exercise significant influence, but do not control and are not the primary beneficiary, are accounted for using the equity method of accounting. Differences in the basis of investments and the separate net asset values of the investees, if any, are amortized into net income or loss over the remaining useful lives of the underlying assets and liabilities, except for the excess related to goodwill. We evaluate our equity method investments for impairment when events or circumstances indicate that the carrying value of the equity method investment may be impaired and that impairment is other than temporary. If an event occurs, we evaluate the recoverability of our carrying value based on the fair value of the investment. If an impairment is indicated, or if we decide to sell an investment in an unconsolidated affiliate, we adjust the carrying values of the asset downward, if necessary, to their estimated fair values.
Asset Retirement Obligations	Asset Retirement Obligations An asset retirement obligation (ARO) is an estimated liability for the cost to retire a tangible asset. We record a liability for legal or contractual obligations to retire our long-lived assets associated with our facilities and right-of-way contracts we hold. We record a liability in the period the obligation is incurred and estimable. An ARO is initially recorded at its estimated fair value with a corresponding increase to property, plant and equipment. This increase in property, plant and equipment is then depreciated over the useful life of the asset to which that liability relates. An ongoing expense is recognized for changes in the fair value of the liability as a result of the passage of time, which we record as depreciation, amortization and accretion expense on our consolidated statements of operations.
Deferred Financing Costs	Deferred Financing Costs Deferred financing costs represent costs associated with obtaining long-term financing and are amortized over the term of the related debt using a method which approximates the effective interest method and has a weighted average remaining life of six years. Our net deferred financing costs are reflected as a reduction of long-term debt on our consolidated balance sheets.
Environmental Costs and Other Contingencies	Environmental Costs and Other Contingencies We recognize liabilities for environmental and other contingencies when there is an exposure that indicates it is both probable that a liability has been incurred and the amount of loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue a liability for that amount. Where the most likely outcome cannot be estimated, a range of potential losses is established and if no one amount in that range is more likely than any other, the low end of the range is accrued. We record liabilities for environmental contingencies at their undiscounted amounts on our consolidated balance sheets as accrued expenses and other liabilities when environmental assessments indicate that remediation efforts are probable and costs can be reasonably estimated. Estimates of our liabilities are based on currently available facts and presently enacted laws and regulations, taking into consideration the likely effects of other societal and economic factors. These estimates are subject to revision in future periods based on actual costs or new circumstances. We capitalize costs that benefit future periods and recognize a current period charge in operations and maintenance expenses when clean-up efforts do not benefit future periods. We evaluate potential recoveries of amounts from third parties, including insurance coverage, separately from our liability. Recovery is evaluated based on the solvency of the third party, among other factors. When recovery is assured, we record and report an asset separately from the associated liability on our consolidated balance sheet.
Revenue Recognition	Revenue Recognition We provide gathering, processing, compression, storage, fractionation, and transportation (consisting of pipelines, truck and rail terminals, truck/trailer units and rail cars) services and we sell commodities (including crude oil, natural gas and NGLs) under various contracts, which are described below. • Fixed-fee contracts . Under these contracts, we do not take title to the underlying crude oil, natural gas, NGLs and water but charge our customers a fixed-fee for the services we provide, which can be a firm reservation charge and/or a charge per volume gathered, processed, compressed, stored, loaded and/or transported (which, in certain contracts, can be subject to a minimum level of volumes). • Percentage-of-proceeds service contracts . Under these contracts, we take title to crude oil, natural gas or NGLs after the commodity leaves our gathering and processing facilities. We often market and sell those commodities to third parties after they leave our facilities and we will remit a portion of the sales proceeds to our producers. • Percentage-of-proceeds product contracts. Under these contracts, we take title to crude oil, natural gas or NGLs before the commodity enters our facilities. We market and sell those commodities to third parties and we will remit a portion of the sales proceeds to our producers. • Purchase and sale contracts . Under these contracts, we purchase crude oil, natural gas or NGLs before the commodity enters our facilities, and we market and sell those commodities to third parties. We recognize revenues for services and products under revenue contracts as our obligations to perform services or deliver/sell products under the contracts are satisfied. A contract’s transaction price is allocated to each performance obligation in the contract and recognized as revenue when, or as, the performance obligation is satisfied. Our fixed-fee contracts and our percentage-of-proceeds service contracts primarily have a single performance obligation to deliver a series of distinct goods or services that are substantially the same and have the same pattern of transfer to our customers. For performance obligations associated with these contracts, we recognize revenues over time utilizing the output method based on the actual volumes of products delivered/sold or services performed, because the single performance obligation is satisfied over time using the same performance measure of progress toward satisfaction of the performance obligation . The transaction price under certain of our fixed-fee contracts and percentage-of-proceeds service contracts includes variable consideration that varies primarily based on actual volumes that are delivered under the contracts. Because the variable consideration specifically relates to our efforts to transfer the services and/or products under the contracts, we allocate the variable consideration entirely to the distinct service, and accordingly recognize the variable consideration as revenues at the time the good or service is transferred to the customer. Certain of our fixed-fee contracts contain minimum volume features under which the customers must utilize our services to gather, compress or load a specified quantity of crude oil or natural gas or pay a deficiency fee based on the difference between actual volumes and the contractual minimum volume. We recognize revenues from these contracts when actual volumes are gathered, compressed or loaded and the likelihood of a customer exercising its remaining rights to make up the deficient volumes under minimum volume commitments becomes remote. We recognize revenues at a point in time for performance obligations associated with our percentage-of proceeds product contracts and purchase and sale contracts, and these revenues are recognized because control of the underlying product is transferred to the customer when the distinct good is provided to the customer. The evaluation of when performance obligations have been satisfied and the transaction price that is allocated to our performance obligations requires significant judgments and assumptions, including our evaluation of the timing of when control of the underlying good or service has transferred to our customers and the relative standalone selling price of goods and services provided to customers under contracts with multiple performance obligations. Actual results can significantly vary from those judgments and assumptions. We did not have any material contracts with multiple performance obligations or under which we receive material amounts of non-cash consideration during the year ended December 31, 2021. Amounts due from our customers under our revenue contracts are typically billed as the service is being provided or on a weekly, bi-weekly or monthly basis and are due within 30 days of billing. Under certain of our contracts, we recognize revenues in excess of billings which we present as contract assets on our consolidated balance sheets. Under certain contracts, we are entitled to receive payments in advance of satisfying our performance obligations under the contracts. We recognize a liability for these payments in excess of revenue recognized and present it as deferred revenue or contract liabilities on our consolidated balance sheets. Our deferred revenue primarily relates to: • Capital Reimbursements. Certain of our contracts require that our customers reimburse us for capital expenditures related to the construction of long-lived assets utilized to provide services to them under the respective revenue contracts. Because we consider these amounts as consideration from customers associated with ongoing services to be provided to customers, we defer these upfront payments in deferred revenue and recognize the amounts in revenue over the life of the associated revenue contract as the performance obligations are satisfied under the contract. • Contracts with Increasing (Decreasing) Rates per Unit. Certain of our contracts have fixed rates per volume that increase and/or decrease over the life of the contract once certain time periods or thresholds are met. We record revenues on these contracts ratably per unit over the life of the contract based on the remaining performance obligations to be performed, which can result in the deferral of revenue for the difference between the consideration received and the ratable revenue recognized.
Credit Risk and Concentrations	Credit Risk and ConcentrationsInherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate.
Income Taxes	Income Taxes Crestwood Equity is a master limited partnership and Crestwood Midstream is a limited partnership. Partnerships are generally not subject to federal income tax, although publicly-traded partnerships are treated as corporations for federal income tax purposes and therefore are subject to federal income tax, unless the partnership generates at least 90% of its gross income from qualifying sources. If the qualifying income requirement is satisfied, the publicly-traded partnership will be treated as a partnership for federal income tax purposes. We satisfy the qualifying income requirement and are treated as a partnership for federal and state income tax purposes. Our consolidated earnings are included in the federal and state income tax returns of our partners. However, legislation in certain states allows for taxation of partnerships, and as such, certain state taxes have been included in our accompanying financial statements as income taxes due to the nature of the tax in those particular states as discussed below. In addition, federal and state income taxes are provided on the earnings of the subsidiaries incorporated as taxable entities. We are required to recognize deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements or tax returns. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial reporting and tax basis of assets and liabilities using expected rates in effect for the year in which the differences are expected to reverse. We are responsible for the Texas Margin tax included in our Texas franchise tax returns. The margin tax qualifies as an income tax under GAAP, which requires us to recognize the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis attributable to such tax. Net earnings for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax basis and the financial reporting basis of assets and liabilities and the taxable income allocation requirements under the partnership agreement.
Price Risk Management Activities	Price Risk Management ActivitiesWe utilize certain derivative financial instruments to (i) manage our exposure to commodity price risk, specifically, the related change in the fair value of inventory, as well as the variability of cash flows related to forecasted transactions; and (ii) ensure the availability of adequate physical supply of commodity. We record all derivative instruments as either assets or liabilities on our consolidated balance sheets at their fair values. Changes in the fair value of these derivative financial instruments are recorded through current earnings.
Unit-Based Compensation	Unit-Based CompensationLong-term incentive awards are granted under the Crestwood Equity Partners LP Long Term Incentive Plan (Crestwood LTIP). Unit-based compensation awards consist of restricted units and performance units that are recognized in our consolidated statements of operations based on their grant date at fair value. For restricted units, we generally recognize the expense over the vesting period on a straight line basis. For performance units, we remeasure compensation expense at each balance sheet date because the vesting is subject to the attainment of certain performance and market goals over a three-year period. For those awards that are settled in cash, the associated liability is remeasured at every balance sheet date through settlement, such that the vested portion of the liability is adjusted to reflect its revised fair value through compensation expense.

Basis of Presentation and Sum_3

Basis of Presentation and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Schedule of Inventory, Current	Our inventory, which is stated at the lower of cost or net realizable value and cost is computed predominantly using the average cost method, consisted of the following ( in millions ): December 31, 2021 2020 NGLs, crude oil and natural gas $ 155.6 $ 88.0 Spare parts 0.9 1.1 Total inventory $ 156.5 $ 89.1
Estimated Useful Lives Of Property, Plant And Equipment	Depreciation is computed using the straight-line method over the estimated useful lives of the assets, as follows: Years Gathering systems and pipelines 15 - 20 Facilities and equipment 3 - 25 Buildings, rights-of-way and easements 1 - 40 Office furniture and fixtures 5- 10 Vehicles 5
Intangible Assets, Useful life	Certain intangible assets are amortized on a straight-line basis over their estimated economic lives, as follows: Weighted-Average Life (years) Customer accounts 22 Revenue contracts 18 Trademarks 10 Our intangible assets consisted of the following ( in millions ): December 31, 2021 2020 Customer accounts (1) $ 488.7 $ 488.7 Revenue contracts 631.2 631.2 Trademarks 6.2 6.2 1,126.1 1,126.1 Less: accumulated amortization 393.2 331.8 Total intangible assets, net $ 732.9 $ 794.3 (1) This amount includes $49.8 million related to customer accounts acquired in conjunction with the NGL Asset Acquisition which is further discussed in Note 3. The following table summarizes total accumulated amortization of our intangible assets ( in millions ): December 31, 2021 2020 Customer accounts $ 183.2 $ 158.5 Revenue contracts 204.6 168.6 Trademarks 5.4 4.7 Total accumulated amortization $ 393.2 $ 331.8
Schedule of Goodwill	The following table summarizes the goodwill of our reporting units ( in millions ). We did not record any impairments of the goodwill associated with our Arrow or NGL Marketing and Logistics reporting units during the years ended December 31, 2021, 2020 and 2019. At December 31, 2021, our accumulated goodwill impairments at CEQP and CMLP were approximately $1,736.8 million and $1,479.6 million, respectively. Goodwill at January 1, 2020 Impairment during the Year Ended December 31, 2020 Goodwill at December 31, 2020 Goodwill at December 31, 2021 Gathering and Processing North Arrow $ 45.9 $ — $ 45.9 $ 45.9 Powder River Basin 80.3 (80.3) — — Storage and Logistics NGL Marketing and Logistics 92.7 — 92.7 92.7 Total $ 218.9 $ (80.3) $ 138.6 $ 138.6

Acquisition and Divestiture (Ta

Acquisition and Divestiture (Tables)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2019
Business Combination and Asset Acquisition [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table summarizes the final valuation of the assets acquired and liabilities assumed at the acquisition date (in millions ): Cash $ 22.5 Other current assets 30.9 Property, plant and equipment 532.9 Intangible assets 306.0 Goodwill 80.3 Current liabilities (30.4) Other long-term liabilities (21.5) Estimated fair value of 100% interest in Jackalope 920.7 Less: Elimination of equity investment in Jackalope 226.7 Gain on acquisition of Jackalope 209.4 Total purchase price $ 484.6
Schedule of Pro Forma Information		The tables below present selected unaudited pro forma information as if the Jackalope Acquisition had occurred on January 1, 2019 (in millions) . The pro forma information is not necessarily indicative of the financial results that would have occurred if the transaction had been completed as of the date indicated. The amounts were calculated after applying our accounting policies and adjusting the results to reflect the depreciation, amortization and accretion expense that would have been charged assuming the fair value adjustments to property, plant and equipment and intangible assets had been made at the beginning of the reporting period. The pro forma net income also includes the effects of interest expense on incremental borrowings and recognition of deferred revenue. Crestwood Equity Year Ended December 31, 2019 Revenues $ 3,202.6 Net income $ 313.5 Crestwood Midstream Year Ended December 31, 2019 Revenues $ 3,202.6 Net income $ 304.2

Certain Balance Sheet Informa_2

Certain Balance Sheet Information (Tables)	12 Months Ended
	Dec. 31, 2021
Balance Sheet Related Disclosures [Abstract]
Property, Plant And Equipment	Property, plant and equipment consisted of the following ( in millions ): CEQP CMLP December 31, December 31, 2021 2020 2021 2020 Gathering systems and pipelines and related assets $ 1,052.5 $ 1,035.2 $ 1,195.2 $ 1,178.0 Facilities and equipment 2,200.6 2,193.5 2,385.8 2,378.6 Buildings, land, rights-of-way, storage rights and easements 391.8 389.0 395.5 392.7 Vehicles 17.0 13.9 14.5 12.1 Construction in process 64.7 83.6 64.7 83.6 Finance leases 12.3 13.3 12.3 13.3 Office furniture and fixtures 32.6 31.1 32.8 31.3 3,771.5 3,759.6 4,100.8 4,089.6 Less: accumulated depreciation 992.1 842.5 1,193.0 1,028.3 Total property, plant and equipment, net $ 2,779.4 $ 2,917.1 $ 2,907.8 $ 3,061.3
Intangible Assets	Certain intangible assets are amortized on a straight-line basis over their estimated economic lives, as follows: Weighted-Average Life (years) Customer accounts 22 Revenue contracts 18 Trademarks 10 Our intangible assets consisted of the following ( in millions ): December 31, 2021 2020 Customer accounts (1) $ 488.7 $ 488.7 Revenue contracts 631.2 631.2 Trademarks 6.2 6.2 1,126.1 1,126.1 Less: accumulated amortization 393.2 331.8 Total intangible assets, net $ 732.9 $ 794.3 (1) This amount includes $49.8 million related to customer accounts acquired in conjunction with the NGL Asset Acquisition which is further discussed in Note 3. The following table summarizes total accumulated amortization of our intangible assets ( in millions ): December 31, 2021 2020 Customer accounts $ 183.2 $ 158.5 Revenue contracts 204.6 168.6 Trademarks 5.4 4.7 Total accumulated amortization $ 393.2 $ 331.8
Schedule of Intangible Assets, Future Amortization Expense	Estimated amortization of our intangible assets for the next five years is as follows ( in millions ): Year Ending December 31, 2022 $ 61.4 2023 $ 57.6 2024 $ 54.2 2025 $ 51.5 2026 $ 51.3
Schedule of Accrued Liabilities	Accrued expenses and other liabilities consisted of the following ( in millions ): December 31, 2021 2020 CMLP Accrued expenses $ 66.3 $ 45.4 Accrued property taxes 4.4 8.4 Income tax payable 0.4 0.2 Interest payable 30.6 24.9 Accrued additions to property, plant and equipment 17.4 12.3 Operating leases 13.2 14.7 Finance leases 1.7 2.9 Contract liabilities 10.7 10.3 Asset retirement obligations 1.4 1.0 Total CMLP accrued expenses and other liabilities $ 146.1 $ 120.1 CEQP Accrued expenses 0.9 1.9 Income tax payable 0.1 — Total CEQP accrued expenses and other liabilities $ 147.1 $ 122.0
Other Noncurrent Liabilities	Other long-term liabilities consisted of the following ( in millions ): December 31, 2021 2020 CMLP Contract liabilities $ 187.1 $ 172.2 Operating leases 19.4 28.5 Asset retirement obligations 34.8 34.1 Other 12.8 17.0 Total CMLP other long-term liabilities $ 254.1 $ 251.8 CEQP Other 4.6 1.5 Total CEQP other long-term liabilities $ 258.7 $ 253.3

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2021
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Asset Retirement Obligations	The following table presents the changes in our net asset retirement obligations ( in millions ): December 31, 2021 2020 Net asset retirement obligations at January 1 $ 35.1 $ 34.8 Liabilities acquired (1) — 0.3 Liabilities incurred — 0.3 Liabilities settled (0.4) (0.8) Accretion expense 1.9 1.9 Other (2) (0.4) (1.4) Net asset retirement obligations at December 31 (3) $ 36.2 $ 35.1 (1) Primarily relates to the NGL Asset Acquisition in 2020. See Note 3 for a further discussion of these acquisitions. (2) Relates to obligations associated with the abandonment and dismantlement of our Marcellus West Union compressor assets in 2021 as further discussed in Note 2 and the obligations included in the sale of our Fayetteville assets in 2020 as further discussed in Note 3. (3) Includes $1.4 million and $1.0 million of current ARO liabilities at December 31, 2021 and 2020.

Investments in Unconsolidated_2

Investments in Unconsolidated Affiliates (Tables)	12 Months Ended
	Dec. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Net Investments and Earnings (Loss) From Unconsolidated Affiliates	Our net investments in and earnings (loss) from our unconsolidated affiliates are as follows ( in millions, unless otherwise stated): Ownership Percentage Investment Earnings (Loss) from Unconsolidated Affiliates December 31, December 31, Year Ended December 31, 2021 2021 2020 2021 2020 2019 Stagecoach Gas Services LLC — % $ — $ 792.5 $ (139.2) $ 37.8 $ 34.2 Tres Palacios Holdings LLC 50.01 % 36.2 35.5 9.3 — 0.9 Powder River Basin Industrial Complex, LLC 50.01 % 3.5 3.6 (0.1) (4.3) (0.2) Crestwood Permian Basin Holdings LLC 50.00 % 116.1 112.1 9.6 (1.0) (5.8) Jackalope Gas Gathering Services, L.L.C. (1) — % — — — — 3.7 Total $ 155.8 $ 943.7 $ (120.4) $ 32.5 $ 32.8 (1) On April 9, 2019, Crestwood Niobrara acquired Williams’s 50% equity interest in Jackalope and, as a result, Crestwood Niobrara controls and owns 100% of the equity interests in Jackalope. Our Jackalope equity investment was previously included in our gathering and processing north segment. See Note 3 for a further discussion of this acquisition.
Equity Method Investments	Financial Position Data December 31, 2021 2020 Current Assets Non-Current Assets Current Liabilities Non-Current Liabilities Members’ Equity Current Assets Non-Current Assets Current Liabilities Non-Current Liabilities Members’ Equity Stagecoach Gas (1) $ — $ — $ — $ — $ — $ 47.4 $ 1,645.5 $ 3.9 $ 1.4 $ 1,687.6 Other (2) 46.5 679.2 58.6 236.5 430.6 23.5 661.9 33.6 233.7 418.1 Total $ 46.5 $ 679.2 $ 58.6 $ 236.5 $ 430.6 $ 70.9 $ 2,307.4 $ 37.5 $ 235.1 $ 2,105.7 (1) As discussed above, in November 2021, we sold our equity interest in our Stagecoach Gas equity investment. (2) Includes our Tres Holdings, PRBIC and Crestwood Permian equity investments. As of December 31, 2021, our equity in the underlying net assets of Tres Holdings exceeded our investment balance by approximately $21.4 million. As of December 31, 2021, our equity in the underlying net assets of PRBIC approximates our investment balance. During the year ended December 31, 2020, we recorded our share of a long-lived asset impairment recorded by our PRBIC equity investment, which eliminated our $5.5 million historical basis difference between our investment and the equity in the underlying net assets of PRBIC. As of December 31, 2021, our equity in the underlying net assets of Crestwood Permian exceeded our investment balance by approximately $8.2 million, and this excess amount is not subject to amortization. Operating Results Data Year Ended December 31, 2021 2020 2019 Operating Revenues Operating Expenses Net Operating Revenues Operating Expenses Net Operating Revenues Operating Expenses Net Stagecoach Gas (1) $ 81.9 $ 456.7 $ (374.6) $ 154.3 $ 78.8 $ 75.5 $ 163.8 $ 83.6 $ 80.6 Other (2) 335.6 300.8 35.0 121.3 146.1 (24.6) 119.9 125.9 (6.0) Total $ 417.5 $ 757.5 $ (339.6) $ 275.6 $ 224.9 $ 50.9 $ 283.7 $ 209.5 $ 74.6 (1) As discussed above, in November 2021, we sold our equity interest in our Stagecoach Gas equity investment and, as a result, the information for the period ended 2021 is presented through November 24, 2021, the date of the Stagecoach Gas divestiture. (2) Includes our Tres Holdings, PRBIC, Crestwood Permian and Jackalope (prior to the acquisition of the remaining 50% interest from Williams in April 2019) equity investments. We amortize the excess basis in certain of our equity investments as an increase in our earnings from unconsolidated affiliates. We recorded amortization of the excess basis in our Tres Holdings equity investment of approximately $1.3 million for each of the years ended December 31, 2021, 2020 and 2019, which we amortize over the life of Tres Palacios’s sublease agreement. We recorded amortization of the excess basis in our PRBIC equity investment of approximately $0.4 million for the year ended December 31, 2019, which we amortized over the life of PRBIC’s property, plant and equipment. We recorded amortization of the excess basis in our Jackalope equity investment of less than $0.1 million for the year ended December 31, 2019, which we amortized over the life of Jackalope’s gathering and processing agreement with Chesapeake Energy Corporation. Distributions and Contributions Distributions (1) Contributions (2) Year Ended December 31, Year Ended December 31, 2021 2020 2019 2021 2020 2019 Stagecoach Gas $ 640.9 $ 59.7 $ 52.3 $ — $ — $ 2.1 Tres Holdings 15.5 6.4 6.3 6.9 6.0 6.3 PRBIC — 0.4 — — — 0.2 Crestwood Permian 16.3 11.9 5.0 10.7 3.4 28.3 Jackalope — — 11.6 — — 24.4 Total $ 672.7 $ 78.4 $ 75.2 $ 17.6 $ 9.4 $ 61.3 (1) In July 2021, Stagecoach Gas closed on the sale of certain of its wholly-owned subsidiaries to a subsidiary of Kinder Morgan and distributed to us approximately $613.9 million as our proportionate share of the gross proceeds received from the sale. We utilized approximately $3 million of these proceeds to pay transaction costs related to the sale described above, $40 million of these proceeds to pay our remaining contingent consideration obligation and related accrued interest described below, and the remaining proceeds to repay a portion of the amounts outstanding under the Crestwood Midstream credit facility. In January 2022, we received cash distributions from Crestwood Permian of approximately $8.5 million. (2) In January 2022, we made cash contributions of approximately $6.0 million and $8.5 million to our Tres Holdings and Crestwood Permian equity investments, respectively.

Risk Management (Tables)

Risk Management (Tables)	12 Months Ended
	Dec. 31, 2021
Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]
Derivatives Not Designated as Hedging Instruments	The following table summarizes the impact to our consolidated statements of operations related to our commodity-based derivatives during the years ended December 31, 2021, 2020 and 2019 ( in millions ): December 31, 2021 2020 2019 Product revenues $ 486.7 $ 214.3 $ 252.3 Gain (loss) reflected in product costs $ (44.5) $ (20.7) $ 19.5
Notional Amounts And Terms Of Company's Derivative Financial Instruments	The notional amounts of our derivative financial instruments include the following: December 31, 2021 December 31, 2020 Fixed Price Fixed Price Fixed Price Fixed Price Propane, ethane, butane, heating oil and crude oil (MMBbls) 71.6 75.8 72.7 76.5 Natural gas (Bcf) 31.9 43.4 22.6 28.6
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table presents the fair value of our commodity derivative instruments with credit-risk-related contingent features and their associated collateral ( in millions ): December 31, 2021 2020 Aggregate fair value liability of derivative instruments with credit-risk-related contingent features (1) $ 57.9 $ 38.5 Broker-related net derivative asset position $ 104.8 $ 35.9 Broker-related cash collateral received $ 76.8 $ 18.3 Cash collateral received, net $ 11.4 $ 12.4 (1) At December 31, 2021 and 2020, we posted $1.5 million and less than $0.1 million of collateral associated with these derivatives.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Assets And Liabilities Measured At Fair Value On Recurring Basis	The following tables set forth by level within the fair value hierarchy, our financial instruments that were accounted for at fair value on a recurring basis at December 31, 2021 and 2020 ( in millions ): December 31, 2021 Level 1 Level 2 Level 3 Gross Fair Value Contract Netting (1) Collateral/Margin Received or Paid Fair Value Assets Assets from price risk management $ 33.3 $ 695.6 $ — $ 728.9 $ (607.4) $ (79.4) $ 42.1 Other investments (2) 2.2 — — 2.2 — — 2.2 Total assets at fair value $ 35.5 $ 695.6 $ — $ 731.1 $ (607.4) $ (79.4) $ 44.3 Liabilities Liabilities from price risk management $ 26.9 $ 686.3 $ — $ 713.2 $ (607.4) $ 8.8 $ 114.6 Total liabilities at fair value $ 26.9 $ 686.3 $ — $ 713.2 $ (607.4) $ 8.8 $ 114.6 December 31, 2020 Level 1 Level 2 Level 3 Gross Fair Value Contract Netting (1) Collateral/Margin Received or Paid Fair Value Assets Assets from price risk management $ 20.2 $ 480.5 $ — $ 500.7 $ (455.0) $ (18.5) $ 27.2 Other investments (2) 2.1 — — 2.1 — — 2.1 Total assets at fair value $ 22.3 $ 480.5 $ — $ 502.8 $ (455.0) $ (18.5) $ 29.3 Liabilities Liabilities from price risk management $ 25.1 $ 494.0 $ — $ 519.1 $ (455.0) $ 12.2 $ 76.3 Total liabilities at fair value $ 25.1 $ 494.0 $ — $ 519.1 $ (455.0) $ 12.2 $ 76.3 (1) Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions. (2) Amount primarily relates to our investment in Suburban Propane Partners, L.P. units which is reflected in other non-current assets on CEQP’s consolidated balance sheets.
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	The following table represents the carrying amount (reduced for deferred financing costs associated with the respective notes) and fair value of our senior notes ( in millions ): December 31, 2021 December 31, 2020 Carrying Amount Fair Carrying Amount Fair 2023 Senior Notes $ — $ — $ 683.8 $ 691.5 2025 Senior Notes $ 496.5 $ 511.9 $ 495.5 $ 509.9 2027 Senior Notes $ 594.2 $ 615.0 $ 593.2 $ 594.1 2029 Senior Notes $ 690.8 $ 727.3 $ — $ —

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Components Of Long-Term Debt	Long-term debt consisted of the following ( in millions ): December 31, 2021 2020 Credit Facility $ 282.0 $ 719.0 2023 Senior Notes — 687.2 2025 Senior Notes 500.0 500.0 2027 Senior Notes 600.0 600.0 2029 Senior Notes 700.0 — Other (1) 0.2 0.4 Less: deferred financing costs, net 29.9 22.6 Total debt 2,052.3 2,484.0 Less: current portion 0.2 0.2 Total long-term debt, less current portion $ 2,052.1 $ 2,483.8
Schedule of Maturities of Long-term Debt	The aggregate maturities of principal amounts on our outstanding long-term debt as of December 31, 2021 for the next five years and in total thereafter are as follows ( in millions ): 2022 $ 0.2 2023 — 2024 — 2025 500.0 2026 282.0 Thereafter 1,300.0 Total debt $ 2,082.2

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Purchase Commitment, Excluding Long-term Commitment	The following table summarizes CEQP’s and CMLP’s self-insurance reserves (in millions) : CEQP CMLP December 31, December 31, 2021 2020 2021 2020 Self-insurance reserves (1) $ 5.5 $ 7.7 $ 4.7 $ 6.7 (1) At December 31, 2021, CEQP and CMLP classified approximately $3.5 million and $2.9 million, respectively of these reserves as other long-term liabilities on their consolidated balance sheets.
Assets And Liabilities, Lessee	The following table summarizes the balance sheet information related to our operating and finance leases ( in millions ): December 31, 2021 2020 Operating leases Operating lease right-of-use assets, net $ 27.4 $ 36.8 Accrued expenses and other liabilities $ 13.2 $ 14.7 Other long-term liabilities 19.4 28.5 Total operating lease liabilities $ 32.6 $ 43.2 Finance leases Property, plant and equipment $ 12.3 $ 13.3 Less: accumulated depreciation 9.2 7.9 Property, plant and equipment, net $ 3.1 $ 5.4 Accrued expenses and other liabilities $ 1.7 $ 2.9 Other long-term liabilities 1.2 1.9 Total finance lease liabilities $ 2.9 $ 4.8
Lease, Cost	The following table presents the weighted-average remaining lease term and the weighted-average discount rate associated with our operating and finance leases: December 31, 2021 2020 Weighted-average remaining lease term (in years) Operating leases (1) 3.9 4.3 Finance leases (2) 2.6 1.7 Weighted-average discount rate Operating leases (3) 5.9 % 6.2 % Finance leases (3) 5.5 % 7.3 % (1) Remaining terms vary from one year to 18 years as of December 31, 2021. (2) Remaining terms vary from one year to five years as of December 31, 2021. (3) As of December 31, 2021 and 2020, we utilized discount rates ranging from 1.5% to 8.3% and 2.6% to 12.8%, respectively, to estimate the discounted cash flows used in estimating our right-of-use assets and lease liabilities, which were primarily based on our credit-adjusted collateralized incremental borrowing rate. in millions ): Year Ended December 31, 2021 2020 2019 Operating leases Operating lease expense (1)(2) $ 20.0 $ 27.2 $ 28.3 Lease income (3) (3.7) (1.7) (1.0) Total operating lease expense, net $ 16.3 $ 25.5 $ 27.3 Finance leases Amortization of right-of-use assets (4) $ 3.0 $ 3.5 $ 3.6 Interest on lease liabilities (5) 0.3 0.5 0.7 Total finance lease expense $ 3.3 $ 4.0 $ 4.3 (1) Approximately $13.4 million, $17.6 million and $17.5 million is included in costs of product/services sold, $3.9 million, $6.7 million and $8.0 million is included in operations and maintenance expense and $2.7 million, $2.9 million and $2.8 million is included in general and administrative expense on our consolidated statements of operations for the years ended December 31, 2021, 2020 and 2019, respectively. (2) Includes short-term and variable lease costs of approximately $2.2 million, $5.5 million and $3.7 million for the years ended December 31, 2021, 2020 and 2019. (3) Included in service revenues on our consolidated statements of operations. (4) Included in depreciation, amortization and accretion expense on our consolidated statements of operations. (5) Included in interest and debt expense, net on our consolidated statements of operations. The following table presents supplemental cash flow information for our operating and finance leases ( in millions ): Year Ended December 31, 2021 2020 2019 Cash paid for lease liabilities Operating cash flows from operating leases $ 19.0 $ 21.3 $ 22.9 Operating cash flows from finance leases $ 0.3 $ 0.5 $ 0.7 Financing cash flows from finance leases $ 2.8 $ 3.1 $ 3.5 Right-of-use assets obtained in exchange for lease obligations Operating leases $ — $ 2.1 $ 4.2 Finance leases $ 1.5 $ 0.4 $ 1.8
Lessee, Operating Lease, Liability, Maturity	The following table presents the future minimum lease liabilities for our leases as of December 31, 2021 for the next five years and in total thereafter ( in millions ): Year Ending December 31, Operating Leases Finance Leases Total 2022 $ 14.6 $ 1.8 $ 16.4 2023 7.5 0.5 8.0 2024 6.6 0.3 6.9 2025 3.2 0.3 3.5 2026 3.0 0.2 3.2 Thereafter 2.0 — 2.0 Total lease payments 36.9 3.1 40.0 Less: interest 4.3 0.2 4.5 Present value of lease liabilities $ 32.6 $ 2.9 $ 35.5

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Assets And Liabilities, Lessee	The following table summarizes the balance sheet information related to our operating and finance leases ( in millions ): December 31, 2021 2020 Operating leases Operating lease right-of-use assets, net $ 27.4 $ 36.8 Accrued expenses and other liabilities $ 13.2 $ 14.7 Other long-term liabilities 19.4 28.5 Total operating lease liabilities $ 32.6 $ 43.2 Finance leases Property, plant and equipment $ 12.3 $ 13.3 Less: accumulated depreciation 9.2 7.9 Property, plant and equipment, net $ 3.1 $ 5.4 Accrued expenses and other liabilities $ 1.7 $ 2.9 Other long-term liabilities 1.2 1.9 Total finance lease liabilities $ 2.9 $ 4.8
Lease, Cost	The following table presents the weighted-average remaining lease term and the weighted-average discount rate associated with our operating and finance leases: December 31, 2021 2020 Weighted-average remaining lease term (in years) Operating leases (1) 3.9 4.3 Finance leases (2) 2.6 1.7 Weighted-average discount rate Operating leases (3) 5.9 % 6.2 % Finance leases (3) 5.5 % 7.3 % (1) Remaining terms vary from one year to 18 years as of December 31, 2021. (2) Remaining terms vary from one year to five years as of December 31, 2021. (3) As of December 31, 2021 and 2020, we utilized discount rates ranging from 1.5% to 8.3% and 2.6% to 12.8%, respectively, to estimate the discounted cash flows used in estimating our right-of-use assets and lease liabilities, which were primarily based on our credit-adjusted collateralized incremental borrowing rate. in millions ): Year Ended December 31, 2021 2020 2019 Operating leases Operating lease expense (1)(2) $ 20.0 $ 27.2 $ 28.3 Lease income (3) (3.7) (1.7) (1.0) Total operating lease expense, net $ 16.3 $ 25.5 $ 27.3 Finance leases Amortization of right-of-use assets (4) $ 3.0 $ 3.5 $ 3.6 Interest on lease liabilities (5) 0.3 0.5 0.7 Total finance lease expense $ 3.3 $ 4.0 $ 4.3 (1) Approximately $13.4 million, $17.6 million and $17.5 million is included in costs of product/services sold, $3.9 million, $6.7 million and $8.0 million is included in operations and maintenance expense and $2.7 million, $2.9 million and $2.8 million is included in general and administrative expense on our consolidated statements of operations for the years ended December 31, 2021, 2020 and 2019, respectively. (2) Includes short-term and variable lease costs of approximately $2.2 million, $5.5 million and $3.7 million for the years ended December 31, 2021, 2020 and 2019. (3) Included in service revenues on our consolidated statements of operations. (4) Included in depreciation, amortization and accretion expense on our consolidated statements of operations. (5) Included in interest and debt expense, net on our consolidated statements of operations. The following table presents supplemental cash flow information for our operating and finance leases ( in millions ): Year Ended December 31, 2021 2020 2019 Cash paid for lease liabilities Operating cash flows from operating leases $ 19.0 $ 21.3 $ 22.9 Operating cash flows from finance leases $ 0.3 $ 0.5 $ 0.7 Financing cash flows from finance leases $ 2.8 $ 3.1 $ 3.5 Right-of-use assets obtained in exchange for lease obligations Operating leases $ — $ 2.1 $ 4.2 Finance leases $ 1.5 $ 0.4 $ 1.8
Lessee, Operating Lease, Liability, Maturity	The following table presents the future minimum lease liabilities for our leases as of December 31, 2021 for the next five years and in total thereafter ( in millions ): Year Ending December 31, Operating Leases Finance Leases Total 2022 $ 14.6 $ 1.8 $ 16.4 2023 7.5 0.5 8.0 2024 6.6 0.3 6.9 2025 3.2 0.3 3.5 2026 3.0 0.2 3.2 Thereafter 2.0 — 2.0 Total lease payments 36.9 3.1 40.0 Less: interest 4.3 0.2 4.5 Present value of lease liabilities $ 32.6 $ 2.9 $ 35.5
Finance Lease, Liability, Fiscal Year Maturity	The following table presents the future minimum lease liabilities for our leases as of December 31, 2021 for the next five years and in total thereafter ( in millions ): Year Ending December 31, Operating Leases Finance Leases Total 2022 $ 14.6 $ 1.8 $ 16.4 2023 7.5 0.5 8.0 2024 6.6 0.3 6.9 2025 3.2 0.3 3.5 2026 3.0 0.2 3.2 Thereafter 2.0 — 2.0 Total lease payments 36.9 3.1 40.0 Less: interest 4.3 0.2 4.5 Present value of lease liabilities $ 32.6 $ 2.9 $ 35.5

Partners' Capital and Non-Con_2

Partners' Capital and Non-Controlling Partner (Tables)	12 Months Ended
	Dec. 31, 2021
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Schedule of Distributions Made to Members or Limited Partners, by Distribution	A summary of CEQP’s limited partner quarterly cash distributions for the years ended December 31, 2021, 2020 and 2019 is presented below: Record Date Payment Date Per Unit Rate Cash Distributions ( in millions ) 2021 February 5, 2021 February 12, 2021 $ 0.625 $ 46.4 May 7, 2021 May 14, 2021 $ 0.625 39.3 August 6, 2021 August 13, 2021 $ 0.625 39.3 November 5, 2021 November 12, 2021 $ 0.625 39.3 $ 164.3 2020 February 7, 2020 February 14, 2020 $ 0.625 $ 45.3 May 8, 2020 May 15, 2020 $ 0.625 45.7 August 7, 2020 August 14, 2020 $ 0.625 45.7 November 6, 2020 November 13, 2020 $ 0.625 46.0 $ 182.7 2019 February 7, 2019 February 14, 2019 $ 0.60 $ 43.1 May 8, 2019 May 15, 2019 $ 0.60 43.1 August 7, 2019 August 14, 2019 $ 0.60 43.1 November 7, 2019 November 14, 2019 $ 0.60 43.1 $ 172.4
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net	The following table shows the change in the interest of our non-controlling partner in subsidiary at December 31, 2021, 2020 and 2019 (in millions) : Balance at December 31, 2018 $ — Reclassification of Series A-2 Preferred Units 178.8 Issuance of Series A-3 Preferred Units 235.0 Distributions to non-controlling partner (18.4) Net income attributable to non-controlling partner 30.8 Balance at December 31, 2019 426.2 Contributions from non-controlling partner 2.8 Distributions to non-controlling partner (37.1) Net income attributable to non-controlling partner 40.8 Balance at December 31, 2020 432.7 Contributions from non-controlling partner 1.0 Distributions to non-controlling partner (40.2) Net income attributable to non-controlling partner 41.1 Balance at December 31, 2021 $ 434.6

Equity Plans (Tables)

Equity Plans (Tables)	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Disclosure of Share-based Compensation Arrangements by Share-based Payment Award	The following table summarizes information regarding restricted, phantom and performance unit activity during the years ended December 31, 2021, 2020 and 2019. Units Weighted-Average Grant Date Fair Value Unvested - January 1, 2019 2,187,970 $ 24.78 Granted - restricted units 988,096 $ 31.48 Granted - phantom units 7,164 $ 29.03 Granted - performance units 238,263 $ 34.21 Vested - restricted units (985,751) $ 23.39 Vested - performance units (32,246) $ 34.21 Forfeited - restricted units (47,547) $ 27.85 Unvested - December 31, 2019 2,355,949 $ 28.94 Granted - restricted units 1,569,451 $ 25.42 Granted - phantom units 17,726 $ 28.48 Granted - performance units 715,674 $ 28.46 Vested - restricted units (906,275) $ 28.75 Vested - phantom units (2,118) $ 26.63 Vested - performance units (846,306) $ 29.85 Forfeited - restricted units (149,001) $ 28.24 Forfeited - phantom units (14,157) $ 27.91 Forfeited - performance units (17,087) $ 27.35 Unvested - December 31, 2020 2,723,856 $ 26.62 Granted - restricted units 1,399,781 $ 20.51 Granted - phantom units 5,795 $ 18.88 Granted - performance units 71,286 $ 25.60 Vested - restricted units (1,148,928) $ 27.65 Vested - phantom units (2,117) $ 26.63 Forfeited - restricted units (48,565) $ 21.67 Unvested - December 31, 2021 3,001,108 $ 23.42

Earnings Per Limited Partner _2

Earnings Per Limited Partner Unit (Tables)	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share	The following table summarizes information regarding the weighted-average of common units excluded during the years ended December 31, 2021, 2020 and 2019 (in millions) : Year Ended December 31, 2021 2020 2019 Preferred units (1) 7.1 7.1 7.1 Crestwood Niobrara’s preferred units (1) 4.2 5.7 — Unit-based compensation performance units (2) 0.2 0.1 — Subordinated units (3) 0.1 0.4 — (1) See Note 12 for additional information regarding the potential conversion of our preferred units and Crestwood Niobrara’s preferred units to common units. (2) For a description of our unit-based compensation performance units, see Note 13. (3) In conjunction with the Crestwood Holdings Transactions, in March 2021, CEQP retired the subordinated units. For additional information regarding the retirement of the subordinated units, see Note 12. The following table shows net income (loss) and weighted-average limited partner units used in computing basic and diluted net income (loss) per limited partner unit for the years ended December 31, 2021, 2020 and 2019 (in millions, except per unit data) : Year Ended December 31, 2021 2020 2019 Common unitholders’ interest in net income (loss) $ (138.6) $ (116.2) $ 223.6 Dilutive effect of net income attributable to subordinated units — — 1.4 Diluted net income (loss) $ (138.6) $ (116.2) $ 225.0 Weighted-average limited partners’ units outstanding - basic 65.6 73.2 71.8 Dilutive effect of Crestwood Niobrara preferred units — — 4.3 Dilutive effect of stock-based compensation performance units — — 0.4 Dilutive effect of subordinated units — — 0.4 Weighted-average limited partners’ units outstanding - diluted 65.6 73.2 76.9 Net income (loss) per limited partner unit: Basic $ (2.11) $ (1.59) $ 3.11 Diluted $ (2.11) $ (1.59) $ 2.93

Segments (Tables)

Segments (Tables)	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Reconciliation of Net Income (Loss) to Earnings Before Interest, Taxes, Depreciation and Amortization]	Below is a reconciliation of CEQP’s and CMLP’s net income (loss) to EBITDA ( in millions ): CEQP CMLP Year Ended December 31, Year Ended December 31, 2021 2020 2019 2021 2020 2019 Net income (loss) $ (37.4) $ (15.3) $ 319.9 $ (44.0) $ (23.4) $ 310.6 Add: Interest and debt expense, net 132.1 133.6 115.4 132.1 133.6 115.4 (Gain) loss on modification/extinguishment of debt 7.5 (0.1) — 7.5 (0.1) — Provision (benefit) for income taxes 0.2 0.4 0.3 0.1 (0.1) 0.3 Depreciation, amortization and accretion 244.2 237.4 195.8 258.4 251.5 209.9 EBITDA $ 346.6 $ 356.0 $ 631.4 $ 354.1 $ 361.5 $ 636.2
Reportable Segments	Segment EBITDA Information Year Ended December 31, 2021 Gathering and Processing North Gathering and Processing South Storage and Logistics Corporate Total Crestwood Midstream Revenues $ 574.7 $ 105.9 $ 3,888.4 $ — $ 4,569.0 Intersegment revenues 459.3 — (459.3) — — Costs of product/services sold 553.2 0.9 3,289.8 — 3,843.9 Operations and maintenance expense 51.1 22.9 47.0 — 121.0 General and administrative expense — — — 90.2 90.2 Gain (loss) on long-lived assets, net 0.4 (40.6) 0.7 0.1 (39.4) Earnings (loss) from unconsolidated affiliates, net — 9.6 (130.0) — (120.4) Crestwood Midstream EBITDA $ 430.1 $ 51.1 $ (37.0) $ (90.1) $ 354.1 Crestwood Equity General and administrative expense — — — 7.4 7.4 Loss on long-lived assets, net — — — (0.2) (0.2) Other income — — — 0.1 0.1 Crestwood Equity EBITDA $ 430.1 $ 51.1 $ (37.0) $ (97.6) $ 346.6 Year Ended December 31, 2020 Gathering and Processing North Gathering and Processing South Storage and Logistics Corporate Total Crestwood Midstream Revenues $ 510.4 $ 121.0 $ 1,622.9 $ — $ 2,254.3 Intersegment revenues 160.5 (0.7) (159.8) — — Costs of product/services sold 261.0 0.5 1,339.0 — 1,600.5 Operations and maintenance expense 55.7 29.2 46.9 — 131.8 General and administrative expense — — — 86.7 86.7 Gain (loss) on long-lived assets, net (3.8) (20.0) (2.4) 0.2 (26.0) Goodwill impairment (80.3) — — — (80.3) Earnings (loss) from unconsolidated affiliates, net — (1.0) 33.5 — 32.5 Crestwood Midstream EBITDA $ 270.1 $ 69.6 $ 108.3 $ (86.5) $ 361.5 Crestwood Equity General and administrative expense — — — 4.8 4.8 Other expense — — — (0.7) (0.7) Crestwood Equity EBITDA $ 270.1 $ 69.6 $ 108.3 $ (92.0) $ 356.0 Year Ended December 31, 2019 Gathering and Processing North Gathering and Processing South Storage and Logistics Corporate Total Crestwood Midstream Revenues $ 686.9 $ 148.9 $ 2,346.1 $ — $ 3,181.9 Intersegment revenues 174.9 0.1 (175.0) — — Costs of product/services sold 524.0 2.1 2,018.8 — 2,544.9 Operations and maintenance expense 60.8 37.9 40.1 — 138.8 General and administrative expense — — — 98.2 98.2 Gain (loss) on long-lived assets, net (4.2) (2.0) (0.2) 0.2 (6.2) Gain on acquisition 209.4 — — — 209.4 Earnings (loss) from unconsolidated affiliates, net 3.7 (5.8) 34.9 — 32.8 Other income, net — — — 0.2 0.2 Crestwood Midstream EBITDA $ 485.9 $ 101.2 $ 146.9 $ (97.8) $ 636.2 Crestwood Equity General and administrative expense — — — 5.2 5.2 Other income — — — 0.4 0.4 Crestwood Equity EBITDA $ 485.9 $ 101.2 $ 146.9 $ (102.6) $ 631.4 Other Segment Information CEQP CMLP Year Ended December 31, Year Ended December 31, 2021 2020 2021 2020 Total Assets Gathering and Processing North $ 2,408.0 $ 2,480.4 $ 2,408.0 $ 2,480.4 Gathering and Processing South 886.5 984.2 1,017.4 1,129.3 Storage and Logistics 1,125.1 1,749.6 1,125.1 1,749.6 Corporate 26.1 29.5 20.7 26.2 Total assets $ 4,445.7 $ 5,243.7 $ 4,571.2 $ 5,385.5 Year Ended December 31, 2021 2020 2019 Purchases of property, plant and equipment Crestwood Midstream Gathering and Processing North $ 66.1 $ 156.5 $ 434.4 Gathering and Processing South 7.9 3.2 13.3 Storage and Logistics 6.6 7.5 5.9 Corporate 0.7 1.1 1.9 Total Crestwood Midstream purchases of property, plant and equipment $ 81.3 $ 168.3 $ 455.5 Crestwood Equity Corporate 1.9 — — Total Crestwood Equity purchases of property, plant and equipment $ 83.2 $ 168.3 $ 455.5

Revenues (Tables)

Revenues (Tables)	12 Months Ended
	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Contract with Customer, Asset and Liability	The following table summarizes our contract assets and contract liabilities (in millions) : December 31, 2021 2020 Contract assets (non-current) $ 1.3 $ 1.0 Contract liabilities (current) (1) $ 10.7 $ 10.3 Contract liabilities (non-current) (1) $ 187.1 $ 172.2 (1) During the year ended December 31, 2021, we recognized revenues of approximately $14.0 million that were previously included in contract liabilities at December 31, 2020. The remaining change in our contract liabilities during the year ended December 31, 2021 related to capital reimbursements associated with our revenue contracts and revenue deferrals associated with our contracts with increasing (decreasing) rates.
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	The following table summarizes the transaction price allocated to our remaining performance obligations under certain contracts that have not been recognized as of December 31, 2021 (in millions) : 2022 $ 72.7 2023 52.6 2024 31.7 2025 0.1 Total $ 157.1
Disaggregation of Revenue	The following tables summarize our revenues from contracts with customers disaggregated by type of product/service sold and by commodity type for each of our segments for the years ended December 31, 2021, 2020 and 2019 ( in millions ). In addition, the revenues from contracts with customers are presented in the three operating and reporting segments that are further discussed in Note 16 for all periods presented. We believe this summary best depicts how the nature, amount, timing and uncertainty of our revenues and cash flows are affected by economic factors. Our non- Topic 606 revenues presented in the tables below primarily represent revenues related to our commodity-based derivatives. Year Ended December 31, 2021 Gathering and Processing North Gathering and Processing South Storage and Logistics Intersegment Elimination Total Topic 606 revenues Gathering Natural gas $ 56.3 $ 83.2 $ — $ — $ 139.5 Crude oil 73.1 — — — 73.1 Water 94.0 — — — 94.0 Processing Natural gas 24.4 5.0 — — 29.4 Compression Natural gas — 17.1 — — 17.1 Storage Crude oil 0.3 — 0.5 (0.3) 0.5 NGLs — — 11.5 — 11.5 Pipeline Crude oil — — 2.6 — 2.6 NGLs — — 0.2 — 0.2 Transportation Crude oil 2.7 — — (0.1) 2.6 NGLs — — 17.3 — 17.3 Rail Loading Crude oil — — 4.6 — 4.6 Product Sales Natural gas 171.4 0.6 326.2 (171.1) 327.1 Crude oil 401.5 — 1,237.7 (82.6) 1,556.6 NGLs 209.4 — 1,796.6 (205.2) 1,800.8 Other — — 1.7 — 1.7 Total Topic 606 revenues 1,033.1 105.9 3,398.9 (459.3) 4,078.6 Non-Topic 606 revenues 0.9 — 489.5 — 490.4 Total revenues $ 1,034.0 $ 105.9 $ 3,888.4 $ (459.3) $ 4,569.0 Year Ended December 31, 2020 Gathering and Processing North Gathering and Processing South Storage and Logistics Intersegment Elimination Total Topic 606 revenues Gathering Natural gas $ 53.4 $ 87.2 $ — $ — $ 140.6 Crude oil 95.3 — — — 95.3 Water 92.6 — — — 92.6 Processing Natural gas 22.4 9.5 — — 31.9 Compression Natural gas — 23.9 — — 23.9 Storage Crude oil 1.1 — 1.9 (0.3) 2.7 NGLs — — 13.1 — 13.1 Pipeline Crude oil — — 4.1 — 4.1 NGLs — — 0.3 — 0.3 Transportation Crude oil 6.2 — 1.9 (0.1) 8.0 NGLs — — 10.9 — 10.9 Rail Loading Crude oil — — 7.4 — 7.4 Product Sales Natural gas 53.7 (0.3) 90.9 (52.8) 91.5 Crude oil 292.2 — 660.7 (53.0) 899.9 NGLs 54.0 — 614.2 (53.6) 614.6 Other — — 1.5 — 1.5 Total Topic 606 revenues 670.9 120.3 1,406.9 (159.8) 2,038.3 Non-Topic 606 revenues — — 216.0 — 216.0 Total revenues 670.9 120.3 1,622.9 (159.8) 2,254.3 Year Ended December 31, 2019 Gathering and Processing North Gathering and Processing South Storage and Logistics Intersegment Elimination Total Topic 606 revenues Gathering Natural gas $ 51.2 $ 112.0 $ — $ — $ 163.2 Crude oil 75.0 — — — 75.0 Water 79.6 — — — 79.6 Processing Natural gas 18.9 10.0 — — 28.9 NGLs — — — — — Compression Natural gas — 24.9 — — 24.9 Storage Crude oil 1.9 — 3.5 (0.4) 5.0 NGLs — — 6.3 — 6.3 Pipeline Crude oil — — 5.2 — 5.2 Transportation Crude oil 7.0 — 5.8 (0.1) 12.7 NGLs — — 11.7 — 11.7 Water — — 0.2 — 0.2 Rail Loading Crude oil — — 11.0 — 11.0 Product Sales Natural gas 55.6 1.2 72.3 (33.4) 95.7 Crude oil 532.1 — 1,315.6 (121.1) 1,726.6 NGLs 40.5 0.9 659.3 (20.0) 680.7 Other — — 1.9 — 1.9 Total Topic 606 revenues 861.8 149.0 2,092.8 (175.0) 2,928.6 Non-Topic 606 revenues — — 253.3 — 253.3 Total revenues $ 861.8 $ 149.0 $ 2,346.1 $ (175.0) $ 3,181.9

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	The (provision) benefit for income taxes for the years ended December 31, 2021, 2020, and 2019 consisted of the following (in millions) : CEQP CMLP Year Ended December 31, Year Ended December 31, 2021 2020 2019 2021 2020 2019 Current: Federal $ (0.4) $ (0.2) $ (0.1) $ — $ 0.1 $ 0.1 State (0.2) (0.1) (0.2) (0.1) — (0.2) Total current (0.6) (0.3) (0.3) (0.1) 0.1 (0.1) Deferred: Federal 0.3 (0.1) 0.1 — — — State 0.1 — (0.1) — — (0.2) Total deferred 0.4 (0.1) — — — (0.2) (Provision) benefit for income taxes $ (0.2) $ (0.4) $ (0.3) $ (0.1) $ 0.1 $ (0.3)
Schedule of Deferred Tax Assets and Liabilities	Components of our deferred income taxes at December 31, 2021 and 2020 are as follows (in millions). CEQP CMLP December 31, December 31, 2021 2020 2021 2020 Total deferred tax asset (1) $ 0.2 $ 0.2 $ — $ — Total deferred tax liability (1) (2.5) (2.9) (0.8) (0.7) Net deferred tax liability $ (2.3) $ (2.7) $ (0.8) $ (0.7)

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2021
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	The following table shows transactions with our affiliates which are reflected in our consolidated statements of operations for the years December 31, 2021, 2020 and 2019 ( in millions ): Year Ended December 31, 2021 2020 2019 Revenues at CEQP and CMLP (1) $ 27.2 $ 27.8 $ 2.9 Costs of product/services sold at CEQP and CMLP (2) $ 136.8 $ 21.0 $ 45.4 Operations and maintenance expenses at CEQP and CMLP charged to our unconsolidated affiliates (3) $ 22.2 $ 21.8 $ 25.9 General and administrative expenses charged by CEQP to CMLP, net (4) $ 35.5 $ 31.1 $ 41.4 General and administrative expenses at CEQP charged to (from) Crestwood Holdings, net (5) $ 4.8 $ 6.5 $ (0.6) (1) Includes (i) $26.2 million, $27.8 million and $1.0 million during the years ended December 31, 2021, 2020 and 2019 related to the sale of NGLs to a subsidiary of Crestwood Permian; (ii) $1.0 million during the year ended December 31, 2021 related to a compressor lease with a subsidiary of Crestwood Permian (iii) $1.2 million during the year ended December 31, 2019 related to the sale of natural gas to a subsidiary of Stagecoach Gas: and (iv) $0.7 million during the year ended December 31, 2019 related to the sale of NGLs to our affiliate, Westlake Chemical Corporation. (2) Includes (i) $110.7 million, $20.0 million and $19.0 million during the years ended December 31, 2021, 2020 and 2019 related to purchases of natural gas and NGLs from a subsidiary of Crestwood Permian; (ii) $11.6 million and $0.6 million during the years ended December 31, 2021 and 2020 related to purchases of natural gas from a subsidiary of Tres Holdings; (iii) $14.5 million, $0.4 million and $23.9 million during the years ended December 31, 2021, 2020 and 2019 related to purchases of NGLs from Ascent Resources - Utica, LLC (Ascent); (iv) $0.2 million during the year ended December 31, 2019 related to purchases of NGLs from Blue Racer Midstream, LLC (Blue Racer); and (v) $2.3 million during the year ended December 31, 2019 related to purchases of natural gas from a subsidiary of Stagecoach Gas. Ascent and Blue Racer are affiliates of Crestwood Holdings for the respective periods presented. (3) We have operating agreements with certain of our unconsolidated affiliates pursuant to which we charge them operations and maintenance expenses in accordance with their respective agreements described above. During the year ended December 31, 2021, we charged $3.4 million to Stagecoach Gas, $4.9 million to Tres Holdings, and $13.9 million to Crestwood Permian under these agreements. During the year ended December 31, 2020, we charged $6.6 million to Stagecoach Gas, $4.1 million to Tres Holdings and $11.1 million to Crestwood Permian under these agreements. During the year ended December 31, 2019, we charged $7.5 million to Stagecoach Gas, $4.4 million to Tres Holdings, $13.5 million to Crestwood Permian and $0.5 million to Jackalope under these agreements. (4) Includes $39.5 million, $35.1 million and $45.1 million of unit-based compensation charges allocated from CEQP to CMLP during the years ended December 31, 2021, 2020 and 2019. In addition, includes $4.0 million, $4.0 million and $3.7 million of CMLP’s general and administrative costs allocated to CEQP during the years ended December 31, 2021, 2020 and 2019. (5) Includes a $4.6 million and $4.4 million reduction of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the years ended December 31, 2021 and 2020 and $1.9 million of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the year ended December 31, 2019. CEQP allocates a portion of its general and administrative costs to Crestwood Holdings and during the years ended December 31, 2021, 2020 and 2019, CEQP allocated $0.2 million, $2.1 million and $1.3 million of its general and administrative costs to Crestwood Holdings.
Schedule of Related Party Receivables and Payables	The following table shows accounts receivable and accounts payable from our affiliates as of December 31, 2021 and 2020 ( in millions ): December 31, 2021 2020 Accounts receivable at CEQP and CMLP $ 8.2 $ 2.5 Accounts payable at CEQP $ 12.0 $ 7.5 Accounts payable at CMLP $ 12.0 $ 5.0

Organization and Description _2

Organization and Description of Business (Details) - USD ($) shares in Millions, $ in Millions	1 Months Ended	12 Months Ended
	Mar. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Partnership Organization And Basis Of Presentation [Line Items]
Payments to acquire units	$ 268	$ 275.6	$ 0	$ 0
Crestwood Equity Partners LP | CMLP
Partnership Organization And Basis Of Presentation [Line Items]
Limited partnership interest		99.90%
Crestwood Equity Partners LP | Crestwood Holdings LP
Partnership Organization And Basis Of Presentation [Line Items]
Limited partnership interest	99.00%
Crestwood Gas Services GP, LLC | CMLP
Partnership Organization And Basis Of Presentation [Line Items]
Limited partnership interest		0.10%
Crestwood Gas Services Holdings LLC | Crestwood Holdings LP
Partnership Organization And Basis Of Presentation [Line Items]
Limited partnership interest		1.00%
Common units
Partnership Organization And Basis Of Presentation [Line Items]
Shares acquired (in shares)	11.5
Subordinated units
Partnership Organization And Basis Of Presentation [Line Items]
Shares acquired (in shares)	0.4

Basis of Presentation and Sum_4

Basis of Presentation and Summary of Significant Accounting Policies (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jan. 01, 2020
Summary Of Significant Accounting Policies [Line Items]
Investments in unconsolidated affiliates	$ 155.8	$ 943.7
Gain (loss) on property, plant and equipment	(39.6)	(26)	$ (6.2)
Goodwill impairment	$ 0	80.3	0
Percentage of gross income from qualifying sources required to be subject to federal income tax, minimum	90.00%
Deferred Financing Costs Weighted Average Remaining Life	6 years
Measurement Input, Discount Rate
Summary Of Significant Accounting Policies [Line Items]
Long-lived measurement input	12.00%
Fayetteville
Summary Of Significant Accounting Policies [Line Items]
Gain (loss) on property, plant and equipment		19.9
Cumulative Effect, Period of Adoption, Adjustment
Summary Of Significant Accounting Policies [Line Items]
Allowance for doubtful accounts				$ 0.7
Partners' capital				$ 0.7
CMLP
Summary Of Significant Accounting Policies [Line Items]
Partners' capital	$ (1,232.3)	(1,805.1)
Investments in unconsolidated affiliates	155.8	943.7
Gain (loss) on property, plant and equipment	(39.4)	(26)	(6.2)
Goodwill impairment	0	80.3	0
Accumulated goodwill impairment	1,479.6
Crestwood Equity Partners LP
Summary Of Significant Accounting Policies [Line Items]
Gain (loss) on property, plant and equipment	(0.2)
Accumulated goodwill impairment	1,736.8
Crestwood Permian Basin Holdings LLC
Summary Of Significant Accounting Policies [Line Items]
Investments in unconsolidated affiliates	$ 116.1	112.1
Equity method ownership percentage	50.00%			50.00%
Crestwood Permian Basin Holdings LLC | Cumulative Effect, Period of Adoption, Adjustment
Summary Of Significant Accounting Policies [Line Items]
Partners' capital				$ (0.2)
Investments in unconsolidated affiliates				$ 0.2
Gathering and Processing South Segment | Marcellus
Summary Of Significant Accounting Policies [Line Items]
Gain (loss) on asset impairment charges	$ 40.1
Arrow | Gathering and Processing North Segment
Summary Of Significant Accounting Policies [Line Items]
Gain (loss) on asset impairment charges		$ 3.1	$ 4.3

Basis of Presentation and Sum_5

Basis of Presentation and Summary of Significant Accounting Policies (Inventory) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Inventory [Line Items]
Inventory	$ 156.5	$ 89.1
NGLs, crude oil and natural gas
Inventory [Line Items]
Inventory	155.6	88
Spare parts
Inventory [Line Items]
Inventory	$ 0.9	$ 1.1

Basis of Presentation and Sum_6

Basis of Presentation and Summary of Significant Accounting Policies (Estimated Useful Lives Of Property, Plant And Equipment) (Details)	12 Months Ended
	Dec. 31, 2021
Gathering systems and pipelines and related assets | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	15 years
Gathering systems and pipelines and related assets | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	20 years
Facilities and equipment | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	3 years
Facilities and equipment | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	25 years
Buildings, land, rights-of-way, storage rights and easements | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	1 year
Buildings, land, rights-of-way, storage rights and easements | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	40 years
Office furniture and fixtures | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	5 years
Office furniture and fixtures | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	10 years
Vehicles | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	5 years

Basis of Presentation and Sum_7

Basis of Presentation and Summary of Significant Accounting Policies (Estimated Economic Lives Of Intangible Assets) (Details)	12 Months Ended
	Dec. 31, 2021
Customer accounts
Finite-Lived Intangible Assets [Line Items]
Weighted-Average Life (years)	22 years
Revenue contracts
Finite-Lived Intangible Assets [Line Items]
Weighted-Average Life (years)	18 years
Trademarks
Finite-Lived Intangible Assets [Line Items]
Weighted-Average Life (years)	10 years

Basis of Presentation and Sum_8

Basis of Presentation and Summary of Significant Accounting Policies (Goodwill, by Reporting Unit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jan. 01, 2020
Goodwill [Line Items]
Goodwill	$ 138.6	$ 138.6		$ 218.9
Goodwill Impairments during the Period	0	(80.3)	$ 0
Arrow
Goodwill [Line Items]
Goodwill	45.9			45.9
Goodwill Impairments during the Period		0
Powder River Basin
Goodwill [Line Items]
Goodwill	0			80.3
Goodwill Impairments during the Period		(80.3)
NGL Marketing and Logistics
Goodwill [Line Items]
Goodwill	92.7			$ 92.7
Goodwill Impairments during the Period		0
CMLP
Goodwill [Line Items]
Goodwill	138.6	138.6
Goodwill Impairments during the Period	$ 0	$ (80.3)	$ 0

Acquisitions and Divestitures (

Acquisitions and Divestitures (Schedules) (Details) - USD ($) $ in Millions	Apr. 09, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Business Acquisition [Line Items]
Investments in unconsolidated affiliates		$ 155.8	$ 943.7
Gain on acquisition		0	0	$ 209.4
Revenues				3,202.6
Net income				313.5
CMLP
Business Acquisition [Line Items]
Investments in unconsolidated affiliates		155.8	943.7
Gain on acquisition		0	0	209.4
Revenues				3,202.6
Net income				304.2
Jackalope Gas Gathering Services, LLC
Business Acquisition [Line Items]
Investments in unconsolidated affiliates		$ 0	$ 0
Jackalope Gas Gathering Services, LLC
Business Acquisition [Line Items]
Cash	$ 22.5
Other current assets	30.9
Property, plant and equipment	532.9
Intangible assets	306
Goodwill	80.3
Current liabilities	(30.4)
Other long-term liabilities	(21.5)
Estimated fair value of 100% interest in Jackalope	920.7
Gain on acquisition	209.4			$ 209.4
Total purchase price	484.6
Jackalope Gas Gathering Services, LLC | Jackalope Gas Gathering Services, LLC
Business Acquisition [Line Items]
Investments in unconsolidated affiliates	$ 226.7

Acquisitions and Divestitures_2

Acquisitions and Divestitures (Narrative) (Details) $ in Millions	Oct. 01, 2020USD ($)	Apr. 09, 2019USD ($)	Apr. 30, 2020USD ($)TerminalsMMBbls	Apr. 30, 2019USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Apr. 08, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net proceeds from issuance of non-controlling interest					$ 175	$ 1	$ 2.8	$ 235
Revenues						4,569	2,254.3	3,181.9
Net income (loss)						$ (37.4)	$ (15.3)	319.9
Valuation Technique, Discounted Cash Flow
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discount rate		12.00%
Jackalope Gas Gathering Services, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity method ownership percentage		50.00%							50.00%
Crestwood Niobrara LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net proceeds from issuance of non-controlling interest				$ 235
Williams Partners LP | Crestwood Niobrara LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Additional voting interest acquired		50.00%
Percentage of ownership		100.00%
Customer accounts
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Weighted average remaining life						22 years
Fayetteville | Discontinued Operations, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Decrease in property, plant and equipment	$ 44.4
Decrease in asset retirement obligation	1.4
Plains All American Pipeline, L.P.
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total purchase price			$ 162
NGL storage capacity | MMBbls			7
Liquid petroleum gas terminals | Terminals			7
Property, plant and equipment			$ 110
Intangible assets			50
Estimated fair value of 100% interest in Jackalope			$ 2
Plains All American Pipeline, L.P. | Customer accounts
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Weighted average remaining life			20 years
Jackalope Gas Gathering Services, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total purchase price		$ 484.6
Property, plant and equipment		532.9
Intangible assets		306
Estimated fair value of 100% interest in Jackalope		$ 920.7
Weighted average remaining life							17 years
Transaction costs							$ 2.8
Revenues								70.1
Net income (loss)								$ 20.9
Jackalope Gas Gathering Services, LLC | Crestwood Niobrara LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net proceeds from issuance of non-controlling interest				$ 235
Percentage of ownership		100.00%
Fayetteville | Gathering and Processing South Segment
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration of sale	23
Gain (loss) on asset impairment charges	$ 19.9

Certain Balance Sheet Informa_3

Certain Balance Sheet Information (Property, Plant And Equipment) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 3,771.5	$ 3,759.6
Less: accumulated depreciation	992.1	842.5
Property, plant and equipment, net	2,779.4	2,917.1
Capitalized interests	0.4	2.7	$ 14.4
Crestwood Equity Partners LP
Property, Plant and Equipment [Line Items]
Property, plant and equipment	3,771.5	3,759.6
Less: accumulated depreciation	992.1	842.5
Property, plant and equipment, net	2,779.4	2,917.1
Depreciation	180.9	174.8	139.5
Crestwood Equity Partners LP | Gathering systems and pipelines and related assets
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,052.5	1,035.2
Crestwood Equity Partners LP | Facilities and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,200.6	2,193.5
Crestwood Equity Partners LP | Buildings, land, rights-of-way, storage rights and easements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	391.8	389
Crestwood Equity Partners LP | Vehicles
Property, Plant and Equipment [Line Items]
Property, plant and equipment	17	13.9
Crestwood Equity Partners LP | Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment	64.7	83.6
Crestwood Equity Partners LP | Office furniture and fixtures
Property, Plant and Equipment [Line Items]
Property, plant and equipment	32.6	31.1
Crestwood Equity Partners LP | Finance leases
Property, Plant and Equipment [Line Items]
Property, plant and equipment	12.3	13.3
CMLP
Property, Plant and Equipment [Line Items]
Property, plant and equipment	4,100.8	4,089.6
Less: accumulated depreciation	1,193	1,028.3
Property, plant and equipment, net	2,907.8	3,061.3
Depreciation	195.1	188.9	$ 153.5
CMLP | Gathering systems and pipelines and related assets
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,195.2	1,178
CMLP | Facilities and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,385.8	2,378.6
CMLP | Buildings, land, rights-of-way, storage rights and easements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	395.5	392.7
CMLP | Vehicles
Property, Plant and Equipment [Line Items]
Property, plant and equipment	14.5	12.1
CMLP | Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment	64.7	83.6
CMLP | Office furniture and fixtures
Property, Plant and Equipment [Line Items]
Property, plant and equipment	32.8	31.3
CMLP | Finance leases
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 12.3	$ 13.3

Certain Balance Sheet Informa_4

Certain Balance Sheet Information (Intangible Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	$ 1,126.1	$ 1,126.1
Less: accumulated amortization	393.2	331.8
Total intangible assets, net	732.9	794.3
Customer accounts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	488.7	488.7
Less: accumulated amortization	183.2	158.5
Customer accounts | Jackalope Gas Gathering Services, LLC
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross		49.8
Revenue contracts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	631.2	631.2
Less: accumulated amortization	204.6	168.6
Trademarks
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	6.2	6.2
Less: accumulated amortization	5.4	4.7
Crestwood Equity Partners LP
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	61.4	60.7	$ 54.6
CMLP
Finite-Lived Intangible Assets [Line Items]
Less: accumulated amortization	$ 393.2	$ 331.8

Certain Balance Sheet Informa_5

Certain Balance Sheet Information (Amortization and Interest Expense, Fiscal Year Maturity) (Details) $ in Millions	Dec. 31, 2021USD ($)
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Amortization Expense, Next Rolling Twelve Months	$ 61.4
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Two	57.6
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Three	54.2
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Four	51.5
Finite-Lived Intangible Assets, Amortization Expense, Rolling Year Five	$ 51.3

Certain Balance Sheet Informa_6

Certain Balance Sheet Information (Accrued Expenses and Other Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Accrued Expenses and Other Liabilities [Line Items]
Operating leases	$ 13.2	$ 14.7
Finance leases	1.7	2.9
Contract liabilities	10.7	10.3
Asset retirement obligations	1.4	1
Accrued expenses and other liabilities	147.1	122
CMLP
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	66.3	45.4
Accrued property taxes	4.4	8.4
Income tax payable	0.4	0.2
Interest payable	30.6	24.9
Accrued additions to property, plant and equipment	17.4	12.3
Operating leases	13.2	14.7
Finance leases	1.7	2.9
Contract liabilities	10.7	10.3
Asset retirement obligations	1.4	1
Accrued expenses and other liabilities	146.1	120.1
Crestwood Equity Partners LP
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	0.9	1.9
Income tax payable	0.1	0
Accrued expenses and other liabilities	$ 147.1	$ 122

Certain Balance Sheet Informa_7

Certain Balance Sheet Information (Other Long-Term Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Contract liabilities	$ 187.1	$ 172.2
Operating leases	19.4	28.5
Asset retirement obligations	34.8	34.1
Other long-term liabilities	258.7	253.3
CMLP
Other long-term liabilities	254.1	251.8
Crestwood Equity Partners LP
Other long-term liabilities	258.7	253.3
Other | CMLP
Other long-term liabilities	12.8	17
Other | Crestwood Equity Partners LP
Other long-term liabilities	$ 4.6	$ 1.5

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Net asset retirement obligations at January 1	$ 35.1	$ 34.8
Liabilities acquired	0	0.3
Liabilities incurred	0	0.3
Liabilities settled	(0.4)	(0.8)
Accretion expense	(1.9)	(1.9)
Other	(0.4)	(1.4)
Net asset retirement obligation at December 31	36.2	35.1
Asset retirement obligations	$ 1.4	$ 1

Investments in Unconsolidated_3

Investments in Unconsolidated Affiliates (Schedule) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jul. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jan. 01, 2020	Apr. 09, 2019	Apr. 08, 2019
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates		$ 155.8	$ 943.7
Earnings (loss) from unconsolidated affiliates, net		(120.4)	32.5	$ 32.8
Distributions(1)		672.7	78.4	75.2
Contributions(2)		17.6	9.4	61.3
Assets, Current		604.7	405.9
Liabilities, Current		598.4	377.8
Revenues		4,569	2,254.3	3,181.9
Operating Expenses		502.4	567	234.8
Net income (loss)		(37.4)	(15.3)	319.9
Equity Method Investment, Nonconsolidated Investee or Group of Investees
Schedule of Equity Method Investments [Line Items]
Assets, Current		46.5	70.9
Assets, Noncurrent		679.2	2,307.4
Liabilities, Current		58.6	37.5
Liabilities, Noncurrent		236.5	235.1
Members' Equity		430.6	2,105.7
Revenues		417.5	275.6	283.7
Operating Expenses		757.5	224.9	209.5
Net income (loss)		$ (339.6)	50.9	74.6
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage		0.00%
Investments in unconsolidated affiliates		$ 0	792.5
Earnings (loss) from unconsolidated affiliates, net		(139.2)	37.8	34.2
Distributions(1)	$ 613.9	640.9	59.7	52.3
Contributions(2)		0	0	2.1
Difference between carrying amount and underlying equity		51.3
Stagecoach Gas Services LLC | Equity Method Investment, Nonconsolidated Investee or Group of Investees
Schedule of Equity Method Investments [Line Items]
Earnings (loss) from unconsolidated affiliates, net		155.6
Assets, Current		0	47.4
Assets, Noncurrent		0	1,645.5
Liabilities, Current		0	3.9
Liabilities, Noncurrent		0	1.4
Members' Equity		0	1,687.6
Revenues		81.9	154.3	163.8
Operating Expenses		456.7	78.8	83.6
Net income (loss)		(374.6)	75.5	80.6
Crestwood Permian Basin LLC
Schedule of Equity Method Investments [Line Items]
Difference between carrying amount and underlying equity		8.2
Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage						50.00%	50.00%
Investments in unconsolidated affiliates		0	0
Earnings (loss) from unconsolidated affiliates, net		0	0	3.7
Distributions(1)		0	0	11.6
Amortization				0.1
Other Equity Method Investments | Equity Method Investment, Nonconsolidated Investee or Group of Investees
Schedule of Equity Method Investments [Line Items]
Assets, Current		46.5	23.5
Assets, Noncurrent		679.2	661.9
Liabilities, Current		58.6	33.6
Liabilities, Noncurrent		236.5	233.7
Members' Equity		430.6	418.1
Revenues		335.6	121.3	119.9
Operating Expenses		300.8	146.1	125.9
Net income (loss)		$ 35	(24.6)	(6)
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage		50.00%			50.00%
Investments in unconsolidated affiliates		$ 116.1	112.1
Earnings (loss) from unconsolidated affiliates, net		9.6	(1)	(5.8)
Distributions(1)		16.3	11.9	5
Contributions(2)		$ 10.7	3.4	28.3
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage		50.01%
Investments in unconsolidated affiliates		$ 36.2	35.5
Earnings (loss) from unconsolidated affiliates, net		9.3	0	0.9
Distributions(1)		15.5	6.4	6.3
Contributions(2)		6.9	6	6.3
Difference between carrying amount and underlying equity		21.4
Amortization		$ 1.3	1.3	1.3
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage		50.01%
Investments in unconsolidated affiliates		$ 3.5	3.6
Earnings (loss) from unconsolidated affiliates, net		(0.1)	(4.3)	(0.2)
Distributions(1)		0	0.4	0
Contributions(2)		0	0	0.2
Difference between carrying amount and underlying equity		5.5
Amortization				0.4
Crestwood Niobrara LLC | Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Contributions(2)		$ 0	$ 0	$ 24.4
Crestwood Niobrara LLC | Williams Partners LP
Schedule of Equity Method Investments [Line Items]
Additional voting interest acquired						50.00%

Investments in Unconsolidated_4

Investments in Unconsolidated Affiliates (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended			12 Months Ended
	Jan. 31, 2022	Nov. 30, 2021	Jul. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jan. 01, 2020	Apr. 09, 2019	Apr. 08, 2019
Schedule of Equity Method Investments [Line Items]
Contributions(2)				$ 17.6	$ 9.4	$ 61.3
Investments in unconsolidated affiliates				155.8	943.7
Contingent consideration				0	38
Earnings (loss) from unconsolidated affiliates, net				(120.4)	32.5	32.8
Net proceeds from sale of long-lived assets, including equity investments				17.7	27.3	0.8
Distributions(1)				672.7	78.4	75.2
Contingent consideration - current portion				0	19
Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates				0	0
Earnings (loss) from unconsolidated affiliates, net				0	0	3.7
Amortization						0.1
Equity method ownership percentage								50.00%	50.00%
Distributions(1)				0	0	11.6
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Contributions(2)				6.9	6	6.3
Investments in unconsolidated affiliates				36.2	35.5
Earnings (loss) from unconsolidated affiliates, net				9.3	0	0.9
Difference between carrying amount and underlying equity				21.4
Amortization				$ 1.3	1.3	1.3
Equity method ownership percentage				50.01%
Distributions(1)				$ 15.5	6.4	6.3
Tres Palacios Holdings LLC | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Contributions(2)	$ 6
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Contributions(2)				0	0	0.2
Investments in unconsolidated affiliates				3.5	3.6
Earnings (loss) from unconsolidated affiliates, net				(0.1)	(4.3)	(0.2)
Difference between carrying amount and underlying equity				$ 5.5
Amortization						0.4
Equity method ownership percentage				50.01%
Distributions(1)				$ 0	0.4	0
Crestwood Permian Basin Holdings | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Distributions(1)	8.5
Crestwood Permian Basin LLC
Schedule of Equity Method Investments [Line Items]
Difference between carrying amount and underlying equity				8.2
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Contributions(2)				0	0	2.1
Investments in unconsolidated affiliates				0	792.5
Earnings (loss) from unconsolidated affiliates, net				(139.2)	37.8	34.2
Difference between carrying amount and underlying equity				$ 51.3
Equity method ownership percentage				0.00%
Distributions(1)			$ 613.9	$ 640.9	59.7	52.3
Proceeds from Sale of Equity Method Investments		$ 15.4	1,195
Equity Method Investment, Transaction Costs			3	3.1
Payment for Contingent Consideration Liability, Operating Activities			$ 40	57
Interest Paid, Including Capitalized Interest, Operating and Investing Activities				2.1
Stagecoach Gas Services LLC | Equity Method Investment, Nonconsolidated Investee or Group of Investees
Schedule of Equity Method Investments [Line Items]
Earnings (loss) from unconsolidated affiliates, net				155.6
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Contributions(2)				10.7	3.4	28.3
Investments in unconsolidated affiliates				116.1	112.1
Earnings (loss) from unconsolidated affiliates, net				$ 9.6	(1)	(5.8)
Equity method ownership percentage				50.00%			50.00%
Distributions(1)				$ 16.3	11.9	5
Crestwood Permian Basin Holdings LLC | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Contributions(2)	$ 8.5
Jackalope Gas Gathering Services, LLC | Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates								$ 226.7
Crestwood Niobrara LLC | Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Contributions(2)				0	0	24.4
Crestwood Niobrara LLC | Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Percentage of ownership								100.00%
CMLP
Schedule of Equity Method Investments [Line Items]
Contributions(2)				17.6	9.4	61.3
Investments in unconsolidated affiliates				155.8	943.7
Contingent consideration				0	38
Earnings (loss) from unconsolidated affiliates, net				(120.4)	32.5	32.8
Net proceeds from sale of long-lived assets, including equity investments				17.7	27.3	$ 0.8
Contingent consideration - current portion				$ 0	$ 19
Williams Partners LP | Crestwood Niobrara LLC
Schedule of Equity Method Investments [Line Items]
Additional voting interest acquired								50.00%
Percentage of ownership								100.00%

Risk Management (Notional Amoun

Risk Management (Notional Amounts and Terms of Company's Derivative Financial Instruments) (Details) bcf in Millions, MMBbls in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)bcfMMBbls	Dec. 31, 2020USD ($)bcfMMBbls	Dec. 31, 2019USD ($)
Derivative [Line Items]
Product revenues	$ 486.7	$ 214.3	$ 252.3
Cash collateral received, net	11.4	12.4
Commodity Contract
Derivative [Line Items]
Gain (loss) reflected in product costs	(44.5)	(20.7)	$ 19.5
Cash collateral received, net	1.5	0.1
Commodity Contract With Credit Contingent Features
Derivative [Line Items]
Aggregate fair value of commodity derivative instruments	57.9	38.5
Broker-related net derivative asset position
Derivative [Line Items]
Broker-related cash collateral received	104.8	35.9
Broker-related cash collateral received
Derivative [Line Items]
Broker-related net derivative asset position	$ 76.8	$ 18.3
Propane, ethane, butane, heating oil and crude oil (MMBbls) | Fixed Price Payor
Derivative [Line Items]
Notional amount | MMBbls	71.6	72.7
Propane, ethane, butane, heating oil and crude oil (MMBbls) | Fixed Price Receiver
Derivative [Line Items]
Notional amount | MMBbls	75.8	76.5
Natural gas (Bcf) | Fixed Price Payor
Derivative [Line Items]
Notional amount | bcf	31.9	22.6
Natural gas (Bcf) | Fixed Price Receiver
Derivative [Line Items]
Notional amount | bcf	43.4	28.6

Risk Management (Narrative) (De

Risk Management (Narrative) (Details) - Price Risk Contracts - Maximum	12 Months Ended
	Dec. 31, 2021
Derivative [Line Items]
Remaining maturity	37 months
Percent of contracts expiring in next twelve months	87.00%

Fair Value Measurements (Assets

Fair Value Measurements (Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Assets
Assets from price risk management	$ 728.9	$ 500.7
SPH units	2.2	2.1
Total assets at fair value	731.1	502.8
Netting Agreements	(607.4)	(455)
Collateral/Margin Received or Paid	(79.4)	(18.5)
Fair Value	42.1	27.2
Total assets at fair value	44.3	29.3
Liabilities
Liabilities from price risk management	713.2	519.1
Total liabilities at fair value	713.2	519.1
Netting Agreements	(607.4)	(455)
Collateral/Margin Received or Paid	8.8	12.2
Fair Value	114.6	76.3
Total liabilities at fair value		76.3
Level 1
Assets
Assets from price risk management	33.3	20.2
SPH units	2.2	2.1
Total assets at fair value	35.5	22.3
Liabilities
Liabilities from price risk management	26.9	25.1
Total liabilities at fair value	26.9	25.1
Level 2
Assets
Assets from price risk management	695.6	480.5
SPH units	0	0
Total assets at fair value	695.6	480.5
Liabilities
Liabilities from price risk management	686.3	494
Total liabilities at fair value	686.3	494
Level 3
Assets
Assets from price risk management	0	0
SPH units	0	0
Total assets at fair value	0	0
Liabilities
Liabilities from price risk management	0	0
Total liabilities at fair value	$ 0	$ 0

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule of Carrying Values and Estimated Fair Values of Senior Notes) (Details) - Crestwood Midstream Senior Notes - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
2023 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	$ 0	$ 687.2
2023 Senior Notes | CMLP
Debt Instrument [Line Items]
Carrying Amount	0	683.8
Fair Value	0	691.5
2025 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	500	500
2025 Senior Notes | CMLP
Debt Instrument [Line Items]
Carrying Amount	496.5	495.5
Fair Value	511.9	509.9
2027 Senior Notes | CMLP
Debt Instrument [Line Items]
Carrying Amount	594.2	593.2
Fair Value	615	594.1
2029 Senior Notes | CMLP
Debt Instrument [Line Items]
Carrying Amount	690.8	0
Fair Value	$ 727.3	$ 0

Long-Term Debt (Components Of L

Long-Term Debt (Components Of Long-Term Debt) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Jan. 31, 2021	Dec. 31, 2020	Apr. 30, 2019
Debt Instrument [Line Items]
Obligations under noncompetition agreements and notes to former owners of businesses acquired	$ 0.2		$ 0.4
Less: deferred financing costs, net	29.9		22.6
Total debt	2,052.3		2,484
Less: current portion	0.2		0.2
Total long-term debt, less current portion	2,052.1		2,483.8
Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Credit agreement outstanding carrying value	282		719
2023 Senior Notes | Crestwood Midstream 2022 senior unsecured notes
Debt Instrument [Line Items]
Carrying Amount	0		687.2
2025 Senior Notes | Crestwood Midstream 2022 senior unsecured notes
Debt Instrument [Line Items]
Carrying Amount	500		500
2027 Senior Notes | Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	600		600	$ 600
2029 Senior Notes | Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	$ 700	$ 700	$ 0

Long-Term Debt (Narrative) (Det

Long-Term Debt (Narrative) (Details)	1 Months Ended	12 Months Ended
	Apr. 30, 2019USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Feb. 01, 2022USD ($)	Jan. 31, 2022USD ($)	Jan. 31, 2021USD ($)
Debt Instrument [Line Items]
Amount of Restricted Net Assets for Consolidated and Unconsolidated Subsidiaries		$ 1,232,300,000
Gains (Losses) on Extinguishment of Debt		7,500,000	$ (100,000)	$ 0
Less: deferred financing costs, net		29,900,000	22,600,000
CMLP
Debt Instrument [Line Items]
Gains (Losses) on Extinguishment of Debt		$ 7,500,000	(100,000)	$ 0
Revolving Loan Facility | CMLP
Debt Instrument [Line Items]
Debt instrument term		5 years
Credit agreement outstanding carrying value		$ 1,500,000,000
Revolving Loan Facility | CMLP | Subsequent Event
Debt Instrument [Line Items]
Credit agreement outstanding carrying value					$ 1,500,000,000	$ 1,250,000,000
Crestwood Midstream Credit Facility
Debt Instrument [Line Items]
Additional borrowings		350,000,000
Crestwood Midstream Credit Facility | Minimum
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Amount		0.0030
Crestwood Midstream Credit Facility | Maximum
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Amount		0.0050
Crestwood Midstream Credit Facility | Letter of Credit
Debt Instrument [Line Items]
Credit agreement outstanding carrying value		$ 350,000,000
Credit Facility
Debt Instrument [Line Items]
Consolidated leverage ratio, maximum		5.50
Credit Facility | Swing Line Loan
Debt Instrument [Line Items]
Credit agreement outstanding carrying value		$ 25,000,000
Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Credit agreement outstanding carrying value		282,000,000	719,000,000
Letters of credit outstanding		$ 6,300,000	$ 23,900,000
Total funded debt to consolidated EBITDA		3.53
Consolidated EBITDA to consolidated interest expense		4.93
Senior Secured Leverage Ratio		0.48
Weighted average interest rate		1.91%	2.45%
Unused borrowing capacity		$ 961,700,000
Interest coverage ratio, minimum		2.50
Senior Secured Leverage Ratio, maximum		3.50
Credit Facility | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Weighted average interest rate		1.90%	2.40%
Credit Facility | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Weighted average interest rate		4.00%	4.50%
Revolving Credit Facility | CMLP
Debt Instrument [Line Items]
Gains (Losses) on Extinguishment of Debt		$ (800,000)
2023 Senior Notes | Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Gains (Losses) on Extinguishment of Debt		$ 6,700,000
Interest rate, stated percentage		6.25%
Repayments of Senior Debt			$ 12,600,000
Extinguishment of Debt, Amount		$ 687,200,000	12,800,000
Interest Paid, Including Capitalized Interest, Operating and Investing Activities		8,600,000
2023 Senior Notes | Crestwood Midstream 2022 senior unsecured notes
Debt Instrument [Line Items]
Carrying amount		0	687,200,000
2023 Senior Notes | Crestwood Midstream 2022 senior unsecured notes | CMLP
Debt Instrument [Line Items]
Carrying amount		$ 0	683,800,000
2025 Senior Notes | Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage		5.75%
2025 Senior Notes | Crestwood Midstream 2022 senior unsecured notes
Debt Instrument [Line Items]
Carrying amount		$ 500,000,000	500,000,000
2025 Senior Notes | Crestwood Midstream 2022 senior unsecured notes | CMLP
Debt Instrument [Line Items]
Carrying amount		496,500,000	495,500,000
2027 Senior Notes | Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Carrying amount	$ 600,000,000	600,000,000	600,000,000
Interest rate, stated percentage	5.625%
2027 Senior Notes | Crestwood Midstream 2019 Senior Notes | CMLP
Debt Instrument [Line Items]
Proceeds from Issuance of Debt	$ 591,100,000
2027 Senior Notes | Crestwood Midstream 2022 senior unsecured notes | CMLP
Debt Instrument [Line Items]
Carrying amount		594,200,000	593,200,000
2029 Senior Notes | Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Carrying amount		700,000,000	0				$ 700,000,000
Interest rate, stated percentage							6.00%
Proceeds from Issuance of Debt		691,000,000
2029 Senior Notes | Crestwood Midstream 2022 senior unsecured notes | CMLP
Debt Instrument [Line Items]
Carrying amount		$ 690,800,000	$ 0
Federal Funds Rate | Revolving Credit Facility | Credit Facility
Debt Instrument [Line Items]
Variable interest rate		0.50%
Eurodollar | Revolving Credit Facility | Crestwood Midstream Credit Facility | Minimum
Debt Instrument [Line Items]
Variable interest rate		1.50%
Eurodollar | Revolving Credit Facility | Crestwood Midstream Credit Facility | Maximum
Debt Instrument [Line Items]
Variable interest rate		2.50%
Eurodollar | Revolving Credit Facility | Credit Facility
Debt Instrument [Line Items]
Variable interest rate		1.00%
Eurodollar | Revolving Credit Facility | Credit Facility | Minimum
Debt Instrument [Line Items]
Variable interest rate		0.50%
Eurodollar | Revolving Credit Facility | Credit Facility | Maximum
Debt Instrument [Line Items]
Variable interest rate		1.50%
Jackalope Gas Gathering Services, LLC
Debt Instrument [Line Items]
Equity Interest	50.00%	50.00%

Long-Term Debt (Maturities of L

Long-Term Debt (Maturities of Long Term Debt) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Total debt	$ 2,052.3	$ 2,484
CMLP
Debt Instrument [Line Items]
2019	0.2
2020	0
2021	0
2022	500
2023	282
Thereafter	1,300
Total debt	$ 2,082.2

Commitments and Contingencies_2

Commitments and Contingencies (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Damages Sought, Value		$ 36
Loss Contingency Accrual, at Carrying Value		16.8	$ 10.4
Accrual for Environmental Loss Contingencies		1	1.3
Purchase Commitment, Remaining Minimum Amount		2,493.6
Loss Contingency, Damages Paid, Value		19.5
Subsequent Event
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Damages Paid, Value	$ 0.1
Other Growth and Maintenance Contractual Purchase Obligations
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Firm Purchase Commitments		15.6
Commodity
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Firm Purchase Commitments		2,760.9
Crestwood Equity Partners LP
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Self-insurance reserves		5.5	7.7
Self-insurance reserve expected to be paid in next fiscal year		3.5
CMLP
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Self-insurance reserves		4.7	$ 6.7
Self-insurance reserve expected to be paid in next fiscal year		2.9
Maximum
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Estimate of Possible Loss		$ 1.9

Commitments and Contingencies L

Commitments and Contingencies Leases (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Total costs of products/services sold	$ 3,843.9	$ 1,600.5	$ 2,544.9
2022	14.6
Operating cash flows from operating leases	19	21.3	22.9
Operating leases	0	2.1	4.2
Operations and maintenance	121	131.8	138.8
Operating lease expense	$ 20	$ 27.2	28.3
Operating lease, weighted average remaining lease term	3 years 10 months 24 days	4 years 3 months 18 days
Operating lease right-of-use assets, net	$ 27.4	$ 36.8
Accrued expenses and other liabilities	147.1	122
Operating leases	19.4	28.5
Total operating lease liabilities	32.6	43.2
Property, plant and equipment	3,771.5	3,759.6
Less: accumulated depreciation	992.1	842.5
Property, plant and equipment, net	2,779.4	2,917.1
Other long-term liabilities	258.7	253.3
Total finance lease liabilities	$ 2.9	$ 4.8
Finance Lease, Weighted Average Remaining Lease Term	2 years 7 months 6 days	1 year 8 months 12 days
Operating Lease, Weighted Average Discount Rate, Percent	5.90%	6.20%
Finance Lease, Weighted Average Discount Rate, Percent	5.50%	7.30%
Lease income	$ (3.7)	$ (1.7)	(1)
Operating Lease Expense, Net	16.3	25.5	27.3
Amortization of right-of-use assets	3	3.5	3.6
Interest on lease liabilities	0.3	0.5	0.7
Finance Lease Expense	3.3	4	4.3
Operating cash flows from finance leases	0.3	0.5	0.7
Payments on finance leases	2.8	3.1	3.5
Finance leases	1.5	$ 0.4	$ 1.8
2022	1.8
2022	16.4
2023	7.5
2023	0.5
2023	8
2024	6.6
2024	0.3
2024	6.9
2025	3.2
2025	0.3
2025	3.5
2026	3
2026	0.2
2026	3.2
Thereafter	2
Thereafter	0
Thereafter	2
Total lease payments	36.9
Total lease payments	3.1
Total lease payments	40
Less: interest	4.3
Less: interest	0.2
Less: interest	4.5
Present value of lease liabilities	$ 35.5
Minimum
Lessee, Lease, Description [Line Items]
Renewal term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Renewal term	10 years

Leases - Balance Sheet Informat

Leases - Balance Sheet Information (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Operating leases
Operating lease right-of-use assets, net	$ 27.4	$ 36.8
Accrued expenses and other liabilities	13.2	14.7
Other long-term liabilities	19.4	28.5
Total operating lease liabilities	32.6	43.2
Finance leases
Property, plant and equipment	12.3	13.3
Less: accumulated depreciation	9.2	7.9
Property, plant and equipment, net	3.1	5.4
Accrued expenses and other liabilities	1.7	2.9
Other long-term liabilities	1.2	1.9
Total finance lease liabilities	$ 2.9	$ 4.8
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Property, plant and equipment, net	Property, plant and equipment, net
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Accrued expenses and other liabilities	Accrued expenses and other liabilities
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Other long-term liabilities	Other long-term liabilities
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Accrued expenses and other liabilities	Accrued expenses and other liabilities
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other long-term liabilities	Other long-term liabilities

Leases - Narrative (Details)

Leases - Narrative (Details)	Dec. 31, 2021
Maximum
Lessee, Lease, Description [Line Items]
Renewal term	10 years
Minimum
Lessee, Lease, Description [Line Items]
Renewal term	1 year

Leases - Weighted Average Remai

Leases - Weighted Average Remaining Lease Term and Discount (Details)	Dec. 31, 2021	Dec. 31, 2020
Weighted-average remaining lease term (in years)
Operating leases	3 years 10 months 24 days	4 years 3 months 18 days
Finance leases	2 years 7 months 6 days	1 year 8 months 12 days
Weighted-average discount rate
Operating leases	5.90%	6.20%
Finance leases	5.50%	7.30%
Minimum
Weighted-average discount rate
Operating lease, remaining lease term	1 year
Finance lease, remaining lease term	1 year
Operating and finance lease, discount rate	1.50%	2.60%
Maximum
Weighted-average discount rate
Operating lease, remaining lease term	18 years
Finance lease, remaining lease term	5 years
Operating and finance lease, discount rate	8.30%	12.80%

Leases - Sublease Income (Detai

Leases - Sublease Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Operating lease expense	$ 20	$ 27.2	$ 28.3
Lease income	(3.7)	(1.7)	(1)
Total operating lease expense, net	16.3	25.5	27.3
Amortization of right-of-use assets	3	3.5	3.6
Interest on lease liabilities	0.3	0.5	0.7
Total finance lease expense	3.3	4	4.3
Total costs of products/services sold	3,843.9	1,600.5	2,544.9
Operations and maintenance	121	131.8	138.8
General and administrative	97.6	91.5	103.4
Short-term lease cost	2.2	5.5	3.7
Operating Leases
Lessee, Lease, Description [Line Items]
Total costs of products/services sold	13.4	17.6	17.5
Operations and maintenance	3.9	6.7	8
General and administrative	$ 2.7	$ 2.9	$ 2.8

Leases - Supplemental Cash Flow

Leases - Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash paid for lease liabilities
Operating cash flows from operating leases	$ 19	$ 21.3	$ 22.9
Operating cash flows from finance leases	0.3	0.5	0.7
Financing cash flows from finance leases	2.8	3.1	3.5
Right-of-use assets obtained in exchange for lease obligations
Operating leases	0	2.1	4.2
Finance leases	$ 1.5	$ 0.4	$ 1.8

Leases - Future Minimum Lease L

Leases - Future Minimum Lease Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Operating leases
2022	$ 14.6
2023	7.5
2024	6.6
2025	3.2
2026	3
Thereafter	2
Total lease payments	36.9
Less: interest	4.3
Total operating lease liabilities	32.6	$ 43.2
Finance Leases
2022	1.8
2023	0.5
2024	0.3
2025	0.3
2026	0.2
Thereafter	0
Total lease payments	3.1
Less: interest	0.2
Total finance lease liabilities	2.9	$ 4.8
Total
2022	16.4
2023	8
2024	6.9
2025	3.5
2026	3.2
Thereafter	2
Total lease payments	40
Less: interest	4.5
Present value of lease liabilities	$ 35.5

Partners' Capital and Non-Con_3

Partners' Capital and Non-Controlling Partner (Schedule of Issuance of Units) (Details) - shares	Dec. 31, 2021	Dec. 31, 2020
Partners' Capital [Abstract]
Units	62,991,511	73,970,208

Partners' Capital and Non-Con_4

Partners' Capital and Non-Controlling Partner (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions

Feb. 14, 2022

Feb. 07, 2022

Nov. 12, 2021

Nov. 05, 2021

Aug. 13, 2021

Aug. 06, 2021

May 14, 2021

May 07, 2021

Feb. 12, 2021

Feb. 05, 2021

Nov. 13, 2020

Nov. 06, 2020

Aug. 14, 2020

Aug. 07, 2020

May 15, 2020

May 08, 2020

Feb. 14, 2020

Feb. 07, 2020

Nov. 14, 2019

Nov. 07, 2019

Aug. 14, 2019

Aug. 07, 2019

May 15, 2019

May 08, 2019

Feb. 14, 2019

Feb. 07, 2019

Jan. 31, 2022

Mar. 31, 2021

Apr. 30, 2019

Dec. 31, 2017

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Apr. 09, 2019

Apr. 08, 2019

Distribution Made to Member or Limited Partner [Line Items]

Distribution to limited partner, distribution date

Nov. 12, 2021

Aug. 13, 2021

May 14, 2021

Feb. 12, 2021

Nov. 13, 2020

Aug. 14, 2020

May 15, 2020

Feb. 14, 2020

Nov. 14, 2019

Aug. 14, 2019

May 15, 2019

Feb. 14, 2019

Maximum Period For Distribution Of Available Cash

45 days

Per unit rate, in dollars per unit

$ 0.625

$ 0.625

$ 0.625

$ 0.625

$ 0.625

$ 0.625

$ 0.625

$ 0.625

$ 0.60

$ 0.60

$ 0.60

$ 0.60

Distributions to partners

$ (164.3)

$ (182.7)

$ (172.4)

Contributions(2)

17.6

9.4

61.3

Distributions paid to non-controlling partners

$ 40.2

$ 37.1

25

Limited partners' units, issued

62,991,511

73,970,208

Preferred units, outstanding (in units)

71,257,445

71,257,445

Preferred units, issued

71,257,445

71,257,445

Distributions to preferred unitholders

$ 60.1

$ 60.1

60.1

Distribution to limited partner, record date

Nov. 5, 2021

Aug. 6, 2021

May 7, 2021

Feb. 5, 2021

Nov. 6, 2020

Aug. 7, 2020

May 8, 2020

Feb. 7, 2020

Nov. 7, 2019

Aug. 7, 2019

May 8, 2019

Feb. 7, 2019

Proceeds from Noncontrolling Interests

$ 175

1

2.8

235

Maximum Value of Common Units to be Issued Under Optional Redemption

100

Payments to acquire units

$ 268

275.6

0

0

Common units

Distribution Made to Member or Limited Partner [Line Items]

Shares acquired (in shares)

11,500,000

Subordinated units

Distribution Made to Member or Limited Partner [Line Items]

Shares acquired (in shares)

400,000

Subsequent Event

Distribution Made to Member or Limited Partner [Line Items]

Distributions to preferred unitholders

$ 15

Crestwood Niobrara LLC

Distribution Made to Member or Limited Partner [Line Items]

Proceeds from Noncontrolling Interests

$ 235

Crestwood Niobrara LLC | Cash distribution

Distribution Made to Member or Limited Partner [Line Items]

Distributions paid to non-controlling partners

40.2

37.1

25

Crestwood Niobrara LLC | Subsequent Event | Cash distribution

Distribution Made to Member or Limited Partner [Line Items]

Distributions paid to non-controlling partners

$ 10.3

CMLP

Distribution Made to Member or Limited Partner [Line Items]

Distributions to partners

(509.7)

(242.6)

(235.8)

Contributions(2)

17.6

9.4

61.3

Distributions paid to non-controlling partners

40.2

37.1

25

Distribution Made to General Partner, Cash Distributions Paid

509.7

242.6

235.8

Proceeds from Noncontrolling Interests

1

2.8

235

Tres Palacios Holdings LLC

Distribution Made to Member or Limited Partner [Line Items]

Contributions(2)

$ 6.9

6

6.3

Equity method ownership percentage

50.01%

Tres Palacios Holdings LLC | Subsequent Event

Distribution Made to Member or Limited Partner [Line Items]

Contributions(2)

$ 6

Jackalope Gas Gathering Services, LLC

Distribution Made to Member or Limited Partner [Line Items]

Equity method ownership percentage

50.00%

50.00%

Equity Interest

50.00%

50.00%

Jackalope Gas Gathering Services, LLC | Crestwood Niobrara LLC

Distribution Made to Member or Limited Partner [Line Items]

Contributions(2)

$ 0

$ 0

$ 24.4

Cash distribution | Subsequent Event

Distribution Made to Member or Limited Partner [Line Items]

Distribution declared per limited partner unit

$ 0.625

Distribution to limited partner, record date

Feb. 7, 2022

Preferred Partner

Distribution Made to Member or Limited Partner [Line Items]

Partners' Capital, Distribution Amount Per Share

$ 0.2567

Partners' Capital, Contingent Distribution Amount Per Share

$ 0.2111

Partner's Capital, Unpaid Distribution, Accrual Percentage

2.8125%

Common Unit Capital

Distribution Made to Member or Limited Partner [Line Items]

Transaction Costs

$ 7.6

Williams Partners LP | Crestwood Niobrara LLC

Distribution Made to Member or Limited Partner [Line Items]

Additional voting interest acquired

50.00%

Partners' Capital and Non-Con_5

Partners' Capital and Non-Controlling Partner (Schedule of Partnership Distributions) (Details) - USD ($) $ / shares in Units, $ in Millions

Feb. 14, 2022

Feb. 07, 2022

Nov. 12, 2021

Nov. 05, 2021

Aug. 13, 2021

Aug. 06, 2021

May 14, 2021

May 07, 2021

Feb. 12, 2021

Feb. 05, 2021

Nov. 13, 2020

Nov. 06, 2020

Aug. 14, 2020

Aug. 07, 2020

May 15, 2020

May 08, 2020

Feb. 14, 2020

Feb. 07, 2020

Nov. 14, 2019

Nov. 07, 2019

Aug. 14, 2019

Aug. 07, 2019

May 15, 2019

May 08, 2019

Feb. 14, 2019

Feb. 07, 2019

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Disclosure Partners Capital Summary Of Quarterly Distributions Of Available Cash [Abstract]

Distribution to limited partner, record date

Nov. 5, 2021

Aug. 6, 2021

May 7, 2021

Feb. 5, 2021

Nov. 6, 2020

Aug. 7, 2020

May 8, 2020

Feb. 7, 2020

Nov. 7, 2019

Aug. 7, 2019

May 8, 2019

Feb. 7, 2019

Distribution to limited partner, distribution date

Nov. 12, 2021

Aug. 13, 2021

May 14, 2021

Feb. 12, 2021

Nov. 13, 2020

Aug. 14, 2020

May 15, 2020

Feb. 14, 2020

Nov. 14, 2019

Aug. 14, 2019

May 15, 2019

Feb. 14, 2019

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.625

$ 0.625

$ 0.625

$ 0.625

$ 0.625

$ 0.625

$ 0.625

$ 0.625

$ 0.60

$ 0.60

$ 0.60

$ 0.60

Distribution amount

$ 39.3

$ 39.3

$ 39.3

$ 46.4

$ 46

$ 45.7

$ 45.7

$ 45.3

$ 43.1

$ 43.1

$ 43.1

$ 43.1

$ 164.3

$ 182.7

$ 172.4

Cash distribution | Subsequent Event

Disclosure Partners Capital Summary Of Quarterly Distributions Of Available Cash [Abstract]

Distribution to limited partner, record date

Feb. 7, 2022

Distribution declared per limited partner unit

$ 0.625

Partners' Capital Net Income (L

Partners' Capital Net Income (Loss) Attributable to NonControlling Partners (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Limited Partners' Capital Account [Line Items]
Net income (loss) attributable to non-controlling partners in subsidiary	$ 41.1	$ 40.8	$ 34.8
CMLP
Limited Partners' Capital Account [Line Items]
Net income (loss) attributable to non-controlling partners in subsidiary	$ 41.1	$ 40.8	$ 34.8

Partners' Capital Rollforward o

Partners' Capital Rollforward of non-controlling interest (Details) - USD ($)	1 Months Ended	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Temporary Equity [Line Items]
Interest of non-controlling partner in subsidiary		$ 434,600,000	$ 432,700,000	$ 426,200,000	$ 0
Non-controlling interest reclassification (Note 12)				178,800,000
Proceeds from Noncontrolling Interests	$ 175,000,000	1,000,000	2,800,000	235,000,000
Temporary Equity, Net Income		41,100,000	40,800,000	30,800,000
Series A-3
Temporary Equity [Line Items]
Proceeds from Noncontrolling Interests				235,000,000
Non-Controlling Partner
Temporary Equity [Line Items]
Proceeds from Noncontrolling Interests		1,000,000	2,800,000
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders		$ (40,200,000)	$ (37,100,000)	$ (18,400,000)

Equity Plans (Schedule of Phant

Equity Plans (Schedule of Phantom and Restricted Unit Activity) (Details) - Crestwood Long-Term Incentive Plan - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Unvested units - December 31, units	2,723,856	2,355,949	2,187,970
Unvested units - December 31	$ 26.62	$ 28.94	$ 24.78
Unvested units - December 31, units	3,001,108	2,723,856	2,355,949
Unvested units - December 31	$ 23.42	$ 26.62	$ 28.94
Restricted units
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Granted, units	1,399,781	1,569,451	988,096
Granted	$ 20.51	$ 25.42	$ 31.48
Vested, units	(1,148,928)	(906,275)	(985,751)
Vested	$ 27.65	$ 28.75	$ 23.39
Canceled, units	(48,565)	(149,001)	(47,547)
Canceled	$ 21.67	$ 28.24	$ 27.85
Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Granted, units	71,286	715,674	238,263
Granted	$ 25.60	$ 28.46	$ 34.21
Vested, units		(846,306)	(32,246)
Vested		$ 29.85	$ 34.21
Canceled, units		(17,087)
Canceled		$ 27.35
Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Granted, units	5,795	17,726	7,164
Granted	$ 18.88	$ 28.48	$ 29.03
Vested, units	(2,117)	(2,118)
Vested	$ 26.63	$ 26.63
Canceled, units		(14,157)
Canceled		$ 27.91

Equity Plans (Narrative) (Detai

Equity Plans (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Feb. 18, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 39,500,000	$ 35,100,000	$ 45,100,000
Employer matching contribution, percent	6.00%
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Percent	10.00%
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Amount	$ 25,000
Common Stock, Shares Authorized	1,500,000
Unit Purchase Plan, Shares Purchased Under Plan	9,932	29,784	6,341
Share-based Payment Arrangement, Nonemployee
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition	1 year
Restricted units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Performance Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Crestwood Long-Term Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation costs not yet recognized	$ 33,200,000	$ 29,700,000
Common units to satisfy employee tax withholding obligations	423,330	581,608	336,548
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition	3 years
Equity Securities
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 4,400,000	$ 1,400,000
Subsequent Event | Crestwood Long-Term Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares reserved for future issuance				2,530,862
Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance multiplier	50.00%
Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance multiplier	200.00%

Earnings Per Limited Partner _3

Earnings Per Limited Partner Unit (Schedule of Reconciliation of Earnings Per Share) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net Income (Loss) Allocated to Limited Partners	$ (138.6)	$ (116.2)	$ 223.6
Net Income (Loss) Allocated to Subordinated Limited Partners	0	0	1.4
Net Income (Loss) Available to Common Stockholders, Diluted	$ (138.6)	$ (116.2)	$ 225
Basic (units)	65.6	73.2	71.8
Dilutive units (units)	0	0	5.1
Weighted Average Limited Partnership Units Outstanding, Diluted	65.6	73.2	76.9
Earnings Per Share, Basic	$ (2.11)	$ (1.59)	$ 3.11
Earnings Per Share, Diluted	$ (2.11)	$ (1.59)	$ 2.93
Niobrara Preferred Units [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Dilutive units (units)	0	0	4.3
Preferred Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of earnings per share	7.1	7.1	7.1
Subordinated units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of earnings per share	0.1	0.4	0
Dilutive units (units)	0	0	0.4
Performance Shares
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of earnings per share	0.2	0.1	0
Dilutive units (units)	0	0	0.4
Crestwood Niobrara LLC | Preferred Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of earnings per share	4.2	5.7	0

Employee Benefit Plan (Details)

Employee Benefit Plan (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Postemployment Benefits [Abstract]
Defined Contribution Plan, Employer Matching Contribution, Percent	90.00%
Defined Benefit Plan, Employee Contributions, Statutory Maximum Per Employee	$ 19,500	$ 19,500	$ 19,000
Defined Contribution Plan Participants Basic Contribution	100.00%
Employer matching contribution, percent	6.00%
Defined Contribution Plan, Requisite Service Period	90 days
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 4,000,000	$ 4,200,000	$ 4,700,000

Segments (Narrative) (Details)

Segments (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)segment	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Revenue, Major Customer [Line Items]
Revenues	$ 4,569	$ 2,254.3	$ 3,181.9
Number of operating segments | segment	3
Crestwood Equity Partners LP
Revenue, Major Customer [Line Items]
Earnings (Losses) Before Interest, Taxes, Depreciation and Amortization from Equity Method Investments	$ 187.4	42.9	42.1
CMLP
Revenue, Major Customer [Line Items]
Revenues	$ 4,569	$ 2,254.3	3,181.9
British Petroleum and its subsidiaries
Revenue, Major Customer [Line Items]
Revenues			$ 333.9

Segments (Reconciliation of Net

Segments (Reconciliation of Net Income (Loss) to EBITDA) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Segment Reporting Information [Line Items]
Net income (loss)	$ (37.4)	$ (15.3)	$ 319.9
Interest and debt expense, net	(132.1)	(133.6)	(115.4)
(Gain) loss on modification/extinguishment of debt	7.5	(0.1)	0
(Provision) benefit for income taxes	0.2	0.4	0.3
Depreciation, amortization and accretion	244.2	237.4	195.8
EBITDA	346.6	356	631.4
CMLP
Segment Reporting Information [Line Items]
Net income (loss)	(44)	(23.4)	310.6
Interest and debt expense, net	(132.1)	(133.6)	(115.4)
(Gain) loss on modification/extinguishment of debt	7.5	(0.1)	0
(Provision) benefit for income taxes	0.1	(0.1)	0.3
Depreciation, amortization and accretion	258.4	251.5	209.9
EBITDA	$ 354.1	$ 361.5	$ 636.2

Segments (Summary Of Segment In

Segments (Summary Of Segment Information) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jan. 01, 2020
Segment Reporting Information [Line Items]
Operating revenues	$ 4,569	$ 2,254.3	$ 3,181.9
Costs of product/services sold	3,843.9	1,600.5	2,544.9
Operations and maintenance	121	131.8	138.8
General and administrative	97.6	91.5	103.4
Gain (loss) on long-lived assets, net	(39.6)	(26)	(6.2)
Goodwill impairment	0	(80.3)	0
Gain on acquisition	0	0	209.4
Earnings (loss) from unconsolidated affiliates, net	(120.4)	32.5	32.8
Other income (expense), net	0.1	(0.7)	0.6
EBITDA	346.6	356	631.4
Goodwill	138.6	138.6		$ 218.9
Assets	4,445.7	5,243.7
Payments to Acquire Property, Plant, and Equipment	83.2	168.3	455.5
CMLP
Segment Reporting Information [Line Items]
Operating revenues	4,569	2,254.3	3,181.9
Costs of product/services sold	3,843.9	1,600.5	2,544.9
Operations and maintenance	121	131.8	138.8
General and administrative	90.2	86.7	98.2
Gain (loss) on long-lived assets, net	(39.4)	(26)	(6.2)
Goodwill impairment	0	(80.3)	0
Gain on acquisition	0	0	209.4
Earnings (loss) from unconsolidated affiliates, net	(120.4)	32.5	32.8
Other income (expense), net	0	0	0.2
EBITDA	354.1	361.5	636.2
Goodwill	138.6	138.6
Assets	4,571.2	5,385.5
Payments to Acquire Property, Plant, and Equipment	81.3	168.3	455.5
Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
General and administrative	7.4	4.8	5.2
Gain (loss) on long-lived assets, net	(0.2)
Other income (expense), net	0.1	(0.7)	0.4
EBITDA	346.6	356	631.4
Assets	4,445.7	5,243.7
Payments to Acquire Property, Plant, and Equipment	83.2	168.3	455.5
Corporate, Non-Segment | CMLP
Segment Reporting Information [Line Items]
Operating revenues	0	0	0
Costs of product/services sold	0	0	0
Operations and maintenance	0	0	0
General and administrative	90.2	86.7	98.2
Gain (loss) on long-lived assets, net	0.1	0.2	0.2
Goodwill impairment		0
Gain on acquisition			0
Earnings (loss) from unconsolidated affiliates, net	0	0	0
Other income (expense), net			0.2
EBITDA	(90.1)	(86.5)	(97.8)
Assets	20.7	26.2
Payments to Acquire Property, Plant, and Equipment	0.7	1.1	1.9
Corporate, Non-Segment | Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
General and administrative	7.4	4.8	5.2
Gain (loss) on long-lived assets, net	(0.2)
Other income (expense), net	0.1	(0.7)	0.4
EBITDA	(97.6)	(92)	(102.6)
Assets	26.1	29.5
Payments to Acquire Property, Plant, and Equipment	1.9	0	0
Intersegment Eliminations
Segment Reporting Information [Line Items]
Operating revenues	(459.3)	(159.8)	(175)
Corporate and Eliminations | CMLP
Segment Reporting Information [Line Items]
Operating revenues	0	0	0
Storage and Logistics | Operating Segments
Segment Reporting Information [Line Items]
Operating revenues	3,888.4	1,622.9	2,346.1
Storage and Logistics | Operating Segments | CMLP
Segment Reporting Information [Line Items]
Operating revenues	3,888.4	1,622.9	2,346.1
Costs of product/services sold	3,289.8	1,339	2,018.8
Operations and maintenance	47	46.9	40.1
General and administrative	0	0	0
Gain (loss) on long-lived assets, net	0.7	(2.4)	(0.2)
Goodwill impairment		0
Gain on acquisition			0
Earnings (loss) from unconsolidated affiliates, net	(130)	33.5	34.9
Other income (expense), net			0
EBITDA	(37)	108.3	146.9
Assets	1,125.1	1,749.6
Payments to Acquire Property, Plant, and Equipment	6.6	7.5	5.9
Storage and Logistics | Operating Segments | Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
General and administrative	0	0	0
Gain (loss) on long-lived assets, net	0
Other income (expense), net	0	0	0
EBITDA	(37)	108.3	146.9
Assets	1,125.1	1,749.6
Storage and Logistics | Intersegment Eliminations | CMLP
Segment Reporting Information [Line Items]
Operating revenues	(459.3)	(159.8)	(175)
Gathering and Processing South Segment | Operating Segments
Segment Reporting Information [Line Items]
Operating revenues	105.9	120.3	149
Gathering and Processing South Segment | Operating Segments | CMLP
Segment Reporting Information [Line Items]
Operating revenues	105.9	121	148.9
Costs of product/services sold	0.9	0.5	2.1
Operations and maintenance	22.9	29.2	37.9
General and administrative	0	0	0
Gain (loss) on long-lived assets, net	(40.6)	(20)	(2)
Goodwill impairment		0
Gain on acquisition			0
Earnings (loss) from unconsolidated affiliates, net	9.6	(1)	(5.8)
Other income (expense), net			0
EBITDA	51.1	69.6	101.2
Assets	1,017.4	1,129.3
Payments to Acquire Property, Plant, and Equipment	7.9	3.2	13.3
Gathering and Processing South Segment | Operating Segments | Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
General and administrative	0	0	0
Gain (loss) on long-lived assets, net	0
Other income (expense), net	0	0	0
EBITDA	51.1	69.6	101.2
Assets	886.5	984.2
Gathering and Processing South Segment | Intersegment Eliminations | CMLP
Segment Reporting Information [Line Items]
Operating revenues	0	(0.7)	0.1
Gathering and Processing North Segment | Operating Segments
Segment Reporting Information [Line Items]
Operating revenues	1,034	670.9	861.8
Gathering and Processing North Segment | Operating Segments | CMLP
Segment Reporting Information [Line Items]
Operating revenues	574.7	510.4	686.9
Costs of product/services sold	553.2	261	524
Operations and maintenance	51.1	55.7	60.8
General and administrative	0	0	0
Gain (loss) on long-lived assets, net	0.4	(3.8)	(4.2)
Goodwill impairment		(80.3)
Gain on acquisition			(209.4)
Earnings (loss) from unconsolidated affiliates, net	0	0	3.7
Other income (expense), net			0
EBITDA	430.1	270.1	485.9
Assets	2,408	2,480.4
Payments to Acquire Property, Plant, and Equipment	66.1	156.5	434.4
Gathering and Processing North Segment | Operating Segments | Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
General and administrative	0	0	0
Gain (loss) on long-lived assets, net	0
Other income (expense), net	0	0	0
EBITDA	430.1	270.1	485.9
Assets	2,408	2,480.4
Gathering and Processing North Segment | Intersegment Eliminations | CMLP
Segment Reporting Information [Line Items]
Operating revenues	$ 459.3	$ 160.5	$ 174.9

Revenues (Details)

Revenues (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Business Acquisition [Line Items]
Contract liabilities	$ 187.1	$ 172.2
ASC 606 Accounts Receivable	$ 331	$ 219.9

Revenues (Contract Assets and L

Revenues (Contract Assets and Liabilities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Revenue from Contract with Customer [Abstract]
Contract assets (non-current)	$ 1.3	$ 1
Contract liabilities	10.7	10.3
Contract liabilities	187.1	$ 172.2
Revenues recognized	$ 14

Revenues (Remaining Performance

Revenues (Remaining Performance Obligations) (Details) $ in Millions	Dec. 31, 2021USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligations, amount	$ 157.1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligations, expected timing of satisfaction, period	1 year
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 obligations, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligations, amount	$ 72.7
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 obligations, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligations, amount	$ 52.6
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 obligations, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligations, amount	$ 31.7
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 obligations, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligations, amount	$ 0.1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2037-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligations, expected timing of satisfaction, period	15 years

Revenues (Disaggregation of Rev

Revenues (Disaggregation of Revenues) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Revenues	$ 4,569	$ 2,254.3	$ 3,181.9
Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	139.5	140.6	163.2
Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	73.1	95.3	75
Water Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	94	92.6	79.6
Natural Gas Processing
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	29.4	31.9	28.9
Natural Gas Compression
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	17.1	23.9	24.9
Crude Oil Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.5	2.7	5
NGL Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	11.5	13.1	6.3
Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	2.6	4.1	5.2
Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	2.6	8	12.7
NGL Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	17.3	10.9	11.7
Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	4.6	7.4	11
Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	327.1	91.5	95.7
Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	1,556.6	899.9	1,726.6
NGL Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	1,800.8	614.6	680.7
Other revenue
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	1.7	1.5	1.9
NGL Processing
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues			0
Water Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues			0.2
NGL Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.2	0.3
Product and Service, Other
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	490.4	216	253.3
Gathering and Processing North Segment | Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	56.3	53.4	51.2
Gathering and Processing North Segment | Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	73.1	95.3	75
Gathering and Processing North Segment | Water Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	94	92.6	79.6
Gathering and Processing North Segment | Natural Gas Processing
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	24.4	22.4	18.9
Gathering and Processing North Segment | Natural Gas Compression
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing North Segment | Crude Oil Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.3	1.1	1.9
Gathering and Processing North Segment | NGL Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing North Segment | Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing North Segment | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	2.7	6.2	7
Gathering and Processing North Segment | NGL Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing North Segment | Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing North Segment | Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	171.4	53.7	55.6
Gathering and Processing North Segment | Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	401.5	292.2	532.1
Gathering and Processing North Segment | NGL Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	209.4	54	40.5
Gathering and Processing North Segment | Other revenue
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing North Segment | NGL Processing
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues			0
Gathering and Processing North Segment | Water Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues			0
Gathering and Processing North Segment | NGL Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0
Gathering and Processing North Segment | Product and Service, Other
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	0.9	0	0
Gathering and Processing South Segment | Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	83.2	87.2	112
Gathering and Processing South Segment | Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing South Segment | Water Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing South Segment | Natural Gas Processing
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	5	9.5	10
Gathering and Processing South Segment | Natural Gas Compression
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	17.1	23.9	24.9
Gathering and Processing South Segment | Crude Oil Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing South Segment | NGL Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing South Segment | Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing South Segment | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing South Segment | NGL Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing South Segment | Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing South Segment | Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.6	(0.3)	1.2
Gathering and Processing South Segment | Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing South Segment | NGL Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0.9
Gathering and Processing South Segment | Other revenue
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Gathering and Processing South Segment | NGL Processing
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues			0
Gathering and Processing South Segment | Water Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues			0
Gathering and Processing South Segment | NGL Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0
Gathering and Processing South Segment | Product and Service, Other
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	0	0	0
Storage and Logistics | Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Storage and Logistics | Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Storage and Logistics | Water Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Storage and Logistics | Natural Gas Processing
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Storage and Logistics | Natural Gas Compression
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Storage and Logistics | Crude Oil Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.5	1.9	3.5
Storage and Logistics | NGL Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	11.5	13.1	6.3
Storage and Logistics | Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	2.6	4.1	5.2
Storage and Logistics | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	1.9	5.8
Storage and Logistics | NGL Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	17.3	10.9	11.7
Storage and Logistics | Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	4.6	7.4	11
Storage and Logistics | Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	326.2	90.9	72.3
Storage and Logistics | Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	1,237.7	660.7	1,315.6
Storage and Logistics | NGL Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	1,796.6	614.2	659.3
Storage and Logistics | Other revenue
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	1.7	1.5	1.9
Storage and Logistics | NGL Processing
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues			0
Storage and Logistics | Water Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues			0.2
Storage and Logistics | NGL Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.2	0.3
Storage and Logistics | Product and Service, Other
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	489.5	216	253.3
Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenues	(459.3)	(159.8)	(175)
Intersegment Eliminations | Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Intersegment Eliminations | Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Intersegment Eliminations | Water Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Intersegment Eliminations | Natural Gas Processing
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Intersegment Eliminations | Natural Gas Compression
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Intersegment Eliminations | Crude Oil Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	(0.3)	(0.3)	(0.4)
Intersegment Eliminations | NGL Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Intersegment Eliminations | Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Intersegment Eliminations | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	(0.1)	(0.1)	(0.1)
Intersegment Eliminations | NGL Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Intersegment Eliminations | Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Intersegment Eliminations | Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	(171.1)	(52.8)	(33.4)
Intersegment Eliminations | Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	(82.6)	(53)	(121.1)
Intersegment Eliminations | NGL Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	(205.2)	(53.6)	(20)
Intersegment Eliminations | Other revenue
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0	0
Intersegment Eliminations | NGL Processing
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues			0
Intersegment Eliminations | Water Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues			0
Intersegment Eliminations | NGL Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0	0
Intersegment Eliminations | Product and Service, Other
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	0	0	0
Operating Segments | Gathering and Processing North Segment
Disaggregation of Revenue [Line Items]
Revenues	1,034	670.9	861.8
Operating Segments | Gathering and Processing South Segment
Disaggregation of Revenue [Line Items]
Revenues	105.9	120.3	149
Operating Segments | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenues	3,888.4	1,622.9	2,346.1
Revenue from Contract with Customer
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	4,078.6	2,038.3	2,928.6
Revenue from Contract with Customer | Gathering and Processing North Segment
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	1,033.1	670.9	861.8
Revenue from Contract with Customer | Gathering and Processing South Segment
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	105.9	120.3	149
Revenue from Contract with Customer | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	3,398.9	1,406.9	2,092.8
Revenue from Contract with Customer | Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	$ (459.3)	$ (159.8)	$ (175)

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Deferred:
Total deferred	$ 0.4	$ (0.1)	$ 0
(Provision) benefit for income taxes	(0.2)	(0.4)	(0.3)
Crestwood Equity Partners LP
Income Tax Contingency [Line Items]
Deferred Tax Assets, Gross	0.2	0.2
Current:
Federal	(0.4)	(0.2)	(0.1)
State	(0.2)	(0.1)	(0.2)
Total current	(0.6)	(0.3)	(0.3)
Deferred:
Federal	0.3	(0.1)	0.1
State	0.1	0	(0.1)
Total deferred	0.4	(0.1)	0
(Provision) benefit for income taxes	(0.2)	(0.4)	(0.3)
Deferred Tax Assets, Net [Abstract]
Total deferred tax liability	(2.5)	(2.9)
Deferred Tax Liabilities, Net [Abstract]
Total deferred tax liability(1)	(2.3)	(2.7)
CMLP
Income Tax Contingency [Line Items]
Deferred Tax Assets, Gross	0	0
Current:
Federal	0	0.1	0.1
State	(0.1)	0	(0.2)
Total current	(0.1)	0.1	(0.1)
Deferred:
Federal	0	0	0
State	0	0	(0.2)
Total deferred	0	0	(0.2)
(Provision) benefit for income taxes	(0.1)	0.1	$ (0.3)
Deferred Tax Assets, Net [Abstract]
Total deferred tax liability	(0.8)	(0.7)
Deferred Tax Liabilities, Net [Abstract]
Total deferred tax liability(1)	$ (0.8)	$ (0.7)

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Apr. 09, 2019
Related Party Transaction [Line Items]
Payments to Acquire Property, Plant, and Equipment	$ 83.2	$ 168.3	$ 455.5
Related Parties Amount in Cost of Sales	136.8	21	45.4
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	22.2	21.8	25.9
Revenues	4,569	2,254.3	3,181.9
Applied Consultants, Inc.
Related Party Transaction [Line Items]
Payments to Acquire Property, Plant, and Equipment	0.6	3.5	9.9
Affiliated Entity
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP(1)	27.2	27.8	2.9
Related Parties Amount in Cost of Sales	136.8	21	45.4
General and administrative expenses charged by CEQP to CMLP, net(4)	35.5	31.1	41.4
Crestwood Permian Basin Holdings LLC
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP(1)	26.2	27.8	1
Related Parties Amount in Cost of Sales	110.7	20	19
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues	1
Ascent Resources - Utica, LLC
Related Party Transaction [Line Items]
Related Parties Amount in Cost of Sales	14.5	0.4	23.9
Blue Racer Midstream, LLC
Related Party Transaction [Line Items]
Related Parties Amount in Cost of Sales			0.2
Stagecoach Gas Services LLC
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP(1)			1.2
Related Parties Amount in Cost of Sales			2.3
Westlake Chemical Corporation
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP(1)			0.7
Tres Palacios Holdings LLC
Related Party Transaction [Line Items]
Related Parties Amount in Cost of Sales	11.6	0.6
CMLP
Related Party Transaction [Line Items]
Payments to Acquire Property, Plant, and Equipment	81.3	168.3	455.5
Related Parties Amount in Cost of Sales	136.8	21	45.4
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues	4,569	2,254.3	3,181.9
CMLP | Affiliated Entity
Related Party Transaction [Line Items]
General and administrative expenses charged by CEQP to CMLP, net(4)	4	4	3.7
Related Party Transaction, Due from (to) Related Party [Abstract]
Accounts payable at CEQP	12	5
Crestwood Equity Partners LP
Related Party Transaction [Line Items]
Payments to Acquire Property, Plant, and Equipment	83.2	168.3	455.5
Related Party Transaction, (Income) Expenses from Transactions with Related Party	4.8	6.5	(0.6)
Crestwood Equity Partners LP | Affiliated Entity
Related Party Transaction [Line Items]
General and administrative expenses charged by CEQP to CMLP, net(4)	0.2	2.1	1.3
Related Party Transaction, Due from (to) Related Party [Abstract]
Accounts receivable at CEQP and CMLP	8.2	2.5
Accounts payable at CEQP	12	7.5
Crestwood Niobrara LLC | Williams Partners LP
Related Party Transaction, Due from (to) Related Party [Abstract]
Percentage of ownership				100.00%
Additional voting interest acquired				50.00%
Crestwood Long-Term Incentive Plan | CMLP
Related Party Transaction [Line Items]
Allocated share based compensation expense	39.5	35.1	45.1
Crestwood Long-Term Incentive Plan | Crestwood Holdings
Related Party Transaction [Line Items]
Allocated share based compensation expense	(4.6)	(4.4)	1.9
Stagecoach Gas Services LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	3.4	6.6	7.5
Tres Palacios Holdings LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	4.9	4.1	4.4
Crestwood Permian Basin Holdings
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	$ 13.9	$ 11.1	13.5
Jackalope Gas Gathering Services, LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party			$ 0.5

Subsequent Events (Details)

Subsequent Events (Details) - Oasis Midstream Partners LP - USD ($) shares in Thousands, $ in Millions	Feb. 01, 2022	Dec. 31, 2021
Subsequent Event [Line Items]
Transaction costs		$ 2.9
Subsequent Event
Subsequent Event [Line Items]
Total purchase price	$ 1,800
Subsequent Event | Oasis Petroleum Inc.
Subsequent Event [Line Items]
Payments to Acquire Businesses, Gross	$ 150
Business Acquisition, Equity Interest Acquired, Number of Shares	33,800
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	21,000
Subsequent Event | Oasis Midstream Public Unitholders
Subsequent Event [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	12,900
Subsequent Event | Oasis Midstream Partners LP
Subsequent Event [Line Items]
Business Acquisition, Equity Interest Acquired, Number of Shares	14,800
Subsequent Event | Oasis Petroleum General Partners
Subsequent Event [Line Items]
Payments to Acquire Businesses, Gross	$ 10

Schedule I - Crestwood Equity_2

Schedule I - Crestwood Equity Partners LP - Parent Only - Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Condensed Financial Statements, Captions [Line Items]
Cash	$ 13.3	$ 14
Total current assets	604.7	405.9
Property, plant and equipment, net	2,779.4	2,917.1
Total assets	4,445.7	5,243.7
Accrued expenses	147.1	122
Total current liabilities	598.4	377.8
Other long-term liabilities	258.7	253.3
Total partners’ capital	1,099.6	1,655.4
Total liabilities and partners’ capital	4,445.7	5,243.7
Prepaid expenses and other current assets	14.8	13.4
Parent Company
Condensed Financial Statements, Captions [Line Items]
Cash	0.2	0.2	$ 0.2	$ 0.2
Total current assets	0.6	0.2
Property, plant and equipment, net	2.5	0.9
Investments in subsidiaries	1,100.1	1,655.7
Other assets	2.1	2.1
Total assets	1,105.3	1,658.9
Accounts payable	0.1	0.1
Accrued expenses	1	1.9
Total current liabilities	1.1	2
Other long-term liabilities	4.6	1.5
Total partners’ capital	1,099.6	1,655.4
Total liabilities and partners’ capital	1,105.3	1,658.9
Prepaid expenses and other current assets	$ 0.4	$ 0

Schedule I - Crestwood Equity_3

Schedule I - Crestwood Equity Partners LP - Parent Only - Statement of Operations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Condensed Financial Statements, Captions [Line Items]
Revenues	$ 4,569	$ 2,254.3	$ 3,181.9
Operating income	222.7	86.8	402.2
Other income (expense), net	0.1	(0.7)	0.6
Net income (loss)	(37.4)	(15.3)	319.9
Net income (loss) attributable to parent	(78.5)	(56.1)	285.1
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(37.4)	(15.3)	320.2
Parent Company
Condensed Financial Statements, Captions [Line Items]
Revenues	0	0	0
Costs and Expenses	7.7	4.9	5.3
Operating income	(7.7)	(4.9)	(5.3)
Loss from unconsolidated affiliates	(70.9)	(50.5)	290
Other income (expense), net	0.1	(0.7)	0.4
Net income (loss) attributable to parent	(78.5)	(56.1)	285.1
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	$ (78.5)	$ (56.1)	$ 285.4

Schedule I - Crestwood Equity_4

Schedule I - Crestwood Equity Partners LP - Parent Only - Statement of Comprehensive Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	$ (37.4)	$ (15.3)	$ 319.9
Change in fair value of Suburban Propane Partners, L.P. units	0	0	0.3
Comprehensive income (loss)	(37.4)	(15.3)	320.2
Parent Company
Condensed Financial Statements, Captions [Line Items]
Change in fair value of Suburban Propane Partners, L.P. units	0	0	0.3
Comprehensive income (loss)	$ (78.5)	$ (56.1)	$ 285.4

Schedule I - Crestwood Equity_5

Schedule I - Crestwood Equity Partners LP - Parent Only - Condensed Statement of Cash Flows (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Mar. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities		$ 426.7	$ 408.1	$ 420.4
Cash flows from investing activities		568.9	(273.3)	(943.7)
Payments on long-term debt		(3,287.5)	(975.8)	(1,729.5)
Distributions to partners		(164.3)	(182.7)	(172.4)
Net cash provided by (used in) financing activities		(996.3)	(146.5)	531.8
Cash at beginning of period		14
Cash at end of period		13.3	14
Payments for Crestwood Holdings Transactions	$ (268)	(275.6)	0	0
Parent Company
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities		(5.5)	(9.4)	(3.7)
Cash flows from investing activities		507.8	242.6	235.8
Distributions to partners		(224.4)	(242.8)	(232.5)
Change in intercompany balances		(2.3)	9.6	0.4
Net cash provided by (used in) financing activities		(502.3)	(233.2)	(232.1)
Net change in cash		0	0	0
Cash at beginning of period		0.2	0.2	0.2
Cash at end of period		0.2	0.2	0.2
Payments for Crestwood Holdings Transactions		$ (275.6)	$ 0	$ 0

Schedule I - Crestwood Equity_6

Schedule I - Crestwood Equity Partners LP - Parent Only - Distributions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Parent Company
Dividends received from CMLP	$ 509.7	$ 242.6	$ 235.8

Schedule II - Crestwood Equit_2

Schedule II - Crestwood Equity Partners LP - Valuation and Qualifying Accounts (Details) - Allowance for Doubtful Accounts - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount	$ 0.9	$ 0.3	$ 0.3
Valuation Allowances and Reserves, Charged to Cost and Expense	0.6	0.5	0.1
Valuation Allowances and Reserves, Charged to Other Accounts	0	0.7	0
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction	(0.9)	(0.6)	(0.1)
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount	$ 0.6	$ 0.9	$ 0.3