Crestwood Equity Partners (CEQP) 10-Q 28 Apr 22 2022 Q1 Quarterly report Financial data

Cover Page

Cover Page - shares	3 Months Ended
	Mar. 31, 2022	Apr. 22, 2022
Document Information [Line Items]
Document Transition Report	false
Document Quarterly Report	true
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity Current Reporting Status	Yes
Entity Address, Address Line One	811 Main Street
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q1
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 Central Index Key	0001136352
Current Fiscal Year End Date	--12-31
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		97,966,187
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
Document Type	10-Q
Document Period End Date	Mar. 31, 2022
Crestwood Midstream Partners LP
Document Information [Line Items]
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity Current Reporting Status	Yes
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q1
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 Central Index Key	0001304464
Current Fiscal Year End Date	--12-31
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		0
Document Type	10-Q
Document Period End Date	Mar. 31, 2022
Common Units
Document Information [Line Items]
Title of 12(b) Security	Common Units representing limited partnership interests
Trading Symbol	CEQP
Security Exchange Name	NYSE
Preferred Units
Document Information [Line Items]
Title of 12(b) Security	Preferred Units representing limited partnership interests
Trading Symbol	CEQP-P
Security Exchange Name	NYSE

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Assets
Cash	$ 11.9	$ 13.3
Accounts receivable, less allowance for doubtful accounts of $0.5 million and $0.6 million at March 31, 2022 and December 31, 2021	485.6	378
Inventory	94	156.5
Assets from price risk management activities	25.5	42.1
Prepaid expenses and other current assets	42.4	14.8
Total current assets	659.4	604.7
Property, plant and equipment	5,047	3,771.5
Less: accumulated depreciation	1,046.6	992.1
Property, plant and equipment, net	4,000.4	2,779.4
Intangible assets	1,623.1	1,126.1
Less: accumulated amortization	412.7	393.2
Intangible assets, net	1,210.4	732.9
Goodwill	177.9	138.6
Operating lease right-of-use assets, net	20.3	27.4
Investments in unconsolidated affiliates	164.8	155.8
Other non-current assets	6.9	6.9
Total assets	6,240.1	4,445.7
Current liabilities:
Accounts payable	446.3	336.5
Accrued expenses and other liabilities	190.3	147.1
Liabilities from price risk management activities	107.6	114.6
Current portion of long-term debt	0.2	0.2
Total current liabilities	744.4	598.4
Long-term debt, less current portion	2,809.9	2,052.1
Other long-term liabilities	283.1	258.7
Deferred income taxes	2.2	2.3
Total liabilities	3,839.6	2,911.5
Commitments and contingencies (Note 9)
Interest of non-controlling partner in subsidiary	434.5	434.6
Partners’ capital:
Crestwood Equity Partners LP partners’ capital (97,980,192 and 62,991,511 common units issued and outstanding at March 31, 2022 and December 31, 2021)	1,354	487.6
Preferred units (71,257,445 units issued and outstanding at both March 31, 2022 and December 31, 2021)	612	612
Total partners’ capital	1,966	1,099.6
Total liabilities and capital	$ 6,240.1	$ 4,445.7
Limited Partners' Capital Account, Units Issued	97,980,192	62,991,511
Limited Partners' Capital Account, Units Outstanding	97,980,192	62,991,511
Preferred Units, Issued	71,257,445	71,257,445
Preferred Units, Outstanding	71,257,445	71,257,445
Crestwood Midstream Partners LP
Assets
Cash	$ 11.3	$ 12.9
Accounts receivable, less allowance for doubtful accounts of $0.5 million and $0.6 million at March 31, 2022 and December 31, 2021	485.6	378
Inventory	94	156.5
Assets from price risk management activities	25.5	42.1
Prepaid expenses and other current assets	42.4	14.4
Total current assets	658.8	603.9
Property, plant and equipment	5,376.2	4,100.8
Less: accumulated depreciation	1,250.9	1,193
Property, plant and equipment, net	4,125.3	2,907.8
Intangible assets	1,623.1	1,126.1
Less: accumulated amortization	412.7	393.2
Intangible assets, net	1,210.4	732.9
Goodwill	177.9	138.6
Operating lease right-of-use assets, net	20.3	27.4
Investments in unconsolidated affiliates	164.8	155.8
Other non-current assets	4.6	4.8
Total assets	6,362.1	4,571.2
Current liabilities:
Accounts payable	446.2	336.4
Accrued expenses and other liabilities	188.9	146.1
Liabilities from price risk management activities	107.6	114.6
Current portion of long-term debt	0.2	0.2
Total current liabilities	742.9	597.3
Long-term debt, less current portion	2,809.9	2,052.1
Other long-term liabilities	281.6	254.1
Deferred income taxes	0.8	0.8
Total liabilities	3,835.2	2,904.3
Commitments and contingencies (Note 9)
Interest of non-controlling partner in subsidiary	434.5	434.6
Partners’ capital:
Partners' capital	2,092.4	1,232.3
Total liabilities and capital	$ 6,362.1	$ 4,571.2

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Allowance for doubtful accounts	$ 0.5	$ 0.6
Limited Partners' Capital Account, Units Issued	97,980,192	62,991,511
Limited Partners' Capital Account, Units Outstanding	97,980,192	62,991,511
Preferred Units, Issued	71,257,445	71,257,445
Preferred Units, Outstanding	71,257,445	71,257,445
Crestwood Midstream Partners LP
Allowance for doubtful accounts	$ 0.5	$ 0.6

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Revenues:
Revenues	$ 1,583.8	$ 1,032.7
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 15)	68.5	41.1
Total costs of product/services sold	1,364.4	813.8
Operating expenses and other:
Operations and maintenance	42.4	32.8
General and administrative	43.4	18.7
Depreciation, amortization and accretion	74.8	59.2
Loss on long-lived assets, net	3.8	1.4
Total expenses	164.4	112.1
Operating income (loss)	55	106.8
Earnings (loss) from unconsolidated affiliates, net	3	(103.7)
Interest and debt expense, net	(36.1)	(36)
Gain (Loss) on Extinguishment of Debt	0	(5.5)
Other income, net	0.3	0
Income (loss) before income taxes	22.2	(38.4)
Benefit for income taxes	0	0.1
Net income (loss)	22.2	(38.3)
Net income attributable to non-controlling partner	10.2	10.1
Net income (loss) attributable to parent	12	(48.4)
Net income attributable to preferred unit holders	15	15
Net loss attributable to partners	$ (3)	$ (63.4)
Net loss per limited partner unit: (Note 12)
Basic (in dollars per share)	$ (0.04)	$ (0.86)
Diluted (in dollars per share)	$ (0.04)	$ (0.86)
Weighted-average limited partners’ units outstanding:
Basic (units)	86	74.1
Diluted (units)	86	74.1
Affiliated Entity
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 15)	$ 68.5	$ 41.1
Crestwood Midstream Partners LP
Revenues:
Revenues	1,583.8	1,032.7
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 15)	68.5	41.1
Total costs of product/services sold	1,364.4	813.8
Operating expenses and other:
Operations and maintenance	42.4	32.8
General and administrative	41.7	17.2
Depreciation, amortization and accretion	78.2	62.8
Loss on long-lived assets, net	3.8	1.4
Total expenses	166.1	114.2
Operating income (loss)	53.3	104.7
Earnings (loss) from unconsolidated affiliates, net	3	(103.7)
Interest and debt expense, net	(36.1)	(36)
Gain (Loss) on Extinguishment of Debt	0	(5.5)
Income (loss) before income taxes	20.2	(40.5)
Benefit for income taxes	0	0.1
Net income (loss)	20.2	(40.4)
Net income attributable to non-controlling partner	10.2	10.1
Net income (loss) attributable to parent	10	(50.5)
Product
Revenues:
Revenues	1,390.5	930.6
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	1,290.8	767.6
Product | Crestwood Midstream Partners LP
Revenues:
Revenues	1,390.5	930.6
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	1,290.8	767.6
Service
Revenues:
Revenues	95.6	97.2
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	5.1	5.1
Service | Crestwood Midstream Partners LP
Revenues:
Revenues	95.6	97.2
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	5.1	5.1
Product, Related Party
Revenues:
Revenues	60.6	4.9
Product, Related Party | Crestwood Midstream Partners LP
Revenues:
Revenues	60.6	4.9
Service, Related Party
Revenues:
Revenues	37.1	0
Service, Related Party | Crestwood Midstream Partners LP
Revenues:
Revenues	$ 37.1	$ 0

Consolidated Statement of Partn

Consolidated Statement of Partners' Capital - USD ($) $ in Millions	Total	Preferred Units	Common unit	Partners' Capital	Crestwood Midstream Partners LP	Crestwood Midstream Partners LPPartners' Capital	Preferred Units	Common Units	Subordinated Units	Common Stock
Preferred units, beginning balance (in units) at Dec. 31, 2020							71,300,000
Partner units, beginning balance (in units) at Dec. 31, 2020								73,600,000	400,000
Beginning balance at Dec. 31, 2020		$ 612	$ 1,043.4	$ 1,655.4		$ 1,805.1
Increase (Decrease) in Partners' Capital [Roll Forward]
Stock Repurchased and Retired During Period, Value			(273.2)	(273.2)
Treasury Stock, Shares, Retired								(11,500,000)	(400,000)
Distributions to partners		(15)	(46.4)	(61.4)		(334)
Unit-based compensation charges (in shares)								1,100,000
Unit-based compensation charges			3.7	3.7		2.3
Taxes paid for unit-based compensation vesting (in shares)								(400,000)
Taxes paid for unit-based compensation vesting			(8.1)	(8.1)		(8.1)
Other			(0.4)	(0.4)		(0.1)
Net income (loss) attributable to parent	$ (48.4)	15	(63.4)	(48.4)	$ (50.5)	(50.5)
Preferred units, ending balance (in units) at Mar. 31, 2021							71,300,000
Partner units, ending balance (in units) at Mar. 31, 2021								62,800,000	0
Ending Balance at Mar. 31, 2021		612	655.6	1,267.6		1,414.7
Preferred units, beginning balance (in units) at Dec. 31, 2021	71,257,445						71,300,000
Partner units, beginning balance (in units) at Dec. 31, 2021								63,000,000
Beginning balance at Dec. 31, 2021		612	487.6	1,099.6	1,232.3	1,232.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(15)	(60.9)	(75.9)		(238.1)
Stock Issued During Period, Value, New Issues			930	930
Stock Issued During Period, Shares, New Issues										33,800,000
Non-cash contribution from partner (Note 11)						1,075.1
Partners' Capital Account, Contributions						14.9
Unit-based compensation charges (in shares)								1,600,000
Unit-based compensation charges			13	13		13
Taxes paid for unit-based compensation vesting (in shares)								(500,000)
Taxes paid for unit-based compensation vesting			(14.9)	(14.9)		(14.9)
Stockholders' Equity, Other Shares	100,000
Other			2.2	2.2		0.1
Net income (loss) attributable to parent	$ 12	15	(3)	12	10	10
Preferred units, ending balance (in units) at Mar. 31, 2022	71,257,445						71,300,000
Partner units, ending balance (in units) at Mar. 31, 2022								98,000,000
Ending Balance at Mar. 31, 2022		$ 612	$ 1,354	$ 1,966	$ 2,092.4	$ 2,092.4

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating activities
Net income (loss)	$ 22.2	$ (38.3)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	74.8	59.2
Amortization of debt-related deferred costs and fair value adjustment	0.8	1.7
Unit-based compensation charges	8.6	2.3
Loss on long-lived assets, net	3.8	1.4
Loss on modification/extinguishment of debt	0	5.5
(Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received	(0.4)	103.8
Deferred income taxes	(0.1)	0
Other Operating Activities, Cash Flow Statement	(0.1)	0.1
Changes in operating assets and liabilities	112.9	122.8
Net cash provided by operating activities	222.5	258.5
Investing activities
Acquisition, net of cash acquired (Note 3)	(145.1)	0
Purchases of property, plant and equipment	(26.4)	(9.3)
Investments in unconsolidated affiliates	(14.5)	(10.2)
Capital distributions from unconsolidated affiliates	5.9	17.3
Net proceeds from sale of assets	0.4	0.2
Net cash used in investing activities	(179.7)	(2)
Financing activities
Proceeds from the issuance of long-term debt	919.1	1,126.3
Payments on long-term debt	(859.1)	(1,018.1)
Payments on finance leases	(0.8)	(0.7)
Payments for deferred financing costs	(1.7)	(11.1)
Payments for Crestwood Holdings Transactions	0	(271.8)
Distributions to partners	(60.9)	(46.4)
Distributions to non-controlling partner	(10.3)	(9.3)
Distributions to preferred unitholders	(15)	(15)
Taxes paid for unit-based compensation vesting	(14.9)	(8.1)
Other	(0.6)	0
Net cash used in financing activities	(44.2)	(254.2)
Net change in cash	(1.4)	2.3
Cash at beginning of period	13.3	14
Cash at end of period	11.9	16.3
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	3.8	(2.2)
Noncash or Part Noncash Acquisition, Current Assets Acquired	63.4
Noncash or Part Noncash Acquisition, Property, Plant and Equipment	1,245.8
Noncash or Part Noncash Acquisition, Intangible Assets Acquired	497
Noncash or Part Noncash Acquisition, Goodwill Acquired	39.3
Noncash or Part Noncash Acquisition, Current Liabilities Assumed	(45.9)
Noncash or Part Noncash Acquisition, Debt Assumed	(698.7)
Noncash or Part Noncash Acquisition, Invested Capital	(930)
Noncash or Part Noncash Acquisition, Other Liabilities Assumed	(25.8)
Noncash or Part Noncash Acquisition, Net Nonmonetary Assets Acquired (Liabilities Assumed)	145.1
Crestwood Midstream Partners LP
Operating activities
Net income (loss)	20.2	(40.4)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	78.2	62.8
Amortization of debt-related deferred costs and fair value adjustment	0.8	1.7
Unit-based compensation charges	8.6	2.3
Loss on long-lived assets, net	3.8	1.4
Loss on modification/extinguishment of debt	0	5.5
(Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received	(0.4)	103.8
Other Operating Activities, Cash Flow Statement	(0.1)	0.1
Changes in operating assets and liabilities	112.8	122
Net cash provided by operating activities	223.9	259.2
Investing activities
Purchases of property, plant and equipment	(26.4)	(9.3)
Investments in unconsolidated affiliates	(14.5)	(10.2)
Capital distributions from unconsolidated affiliates	5.9	17.3
Net proceeds from sale of assets	0.4	0.2
Net cash used in investing activities	(34.6)	(2)
Financing activities
Proceeds from the issuance of long-term debt	919.1	1,126.3
Payments on long-term debt	(859.1)	(1,018.1)
Payments on finance leases	(0.8)	(0.7)
Payments for deferred financing costs	(1.7)	(11.1)
Proceeds from Contributions from Parent	14.9	0
Distributions to partners	(238.1)	(334)
Distributions to non-controlling partner	(10.3)	(9.3)
Taxes paid for unit-based compensation vesting	(14.9)	(8.1)
Net cash used in financing activities	(190.9)	(255)
Net change in cash	(1.6)	2.2
Cash at beginning of period	12.9	13.7
Cash at end of period	11.3	15.9
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	3.8	$ (2.2)
Noncash or Part Noncash Acquisition, Current Assets Acquired	63.4
Noncash or Part Noncash Acquisition, Property, Plant and Equipment	1,245.8
Noncash or Part Noncash Acquisition, Intangible Assets Acquired	497
Noncash or Part Noncash Acquisition, Goodwill Acquired	39.3
Noncash or Part Noncash Acquisition, Current Liabilities Assumed	(45.9)
Noncash or Part Noncash Acquisition, Debt Assumed	(698.7)
Noncash or Part Noncash Acquisition, Other Liabilities Assumed	(25.8)
Crestwood Midstream Partners LP | Oasis Midstream Partners LP
Supplemental schedule of noncash investing activities
Noncash Contribution From Parent	$ 1,075.1

Organization and Business Descr

Organization and Business Description	3 Months Ended
	Mar. 31, 2022
Disclosure Partnership Organization And Basis Of Presentation Narrative [Abstract]
Organization and Business Description	Organization and Business Description The accompanying notes to the consolidated financial statements apply to Crestwood Equity Partners LP (Crestwood Equity or CEQP) and Crestwood Midstream Partners LP (Crestwood Midstream or CMLP), unless otherwise indicated. The accompanying consolidated financial statements and related notes should be read in conjunction with our 2021 Annual Report on Form 10-K filed with the Securities and Exchange Commission (SEC) on February 25, 2022. The financial information as of March 31, 2022, and for the three months ended March 31, 2022 and 2021, is unaudited. The consolidated balance sheets as of December 31, 2021 were derived from the audited balance sheets filed in our 2021 Annual Report on Form 10-K. 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 either Crestwood Midstream Partners LP itself or Crestwood Midstream Partners LP and its consolidated subsidiaries. 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. 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. Business Description 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 natural gas liquids (NGLs), 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. See Note 13 for information regarding our operating and reporting segments.

Basis of Presentation and Summa

Basis of Presentation and Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2022
Accounting Policies [Abstract]
Basis of Presentation and Significant Accounting Policies	Basis of Presentation and Summary of Significant Accounting Policies Basis of Presentation Our consolidated financial statements are prepared in accordance with Generally Accepted Accounting Principles (GAAP) and include the accounts of all consolidated subsidiaries after the elimination of all intercompany accounts and transactions. 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. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC. Significant Accounting Policies There were no material changes in our significant accounting policies from those described in our 2021 Annual Report on Form 10-K.

Acquisitions

Acquisitions	3 Months Ended
	Mar. 31, 2022
Business Combination and Asset Acquisition [Abstract]
Acquisitions and Divestitures	Acquisition On October 25, 2021, we entered into a merger agreement to acquire Oasis Midstream Partners LP (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 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 20.9 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 in exchange for its ownership of the general partner of Oasis Midstream. We accounted for the Merger as a business combination using the acquisition method of accounting. In addition, the purchase accounting reflects the adoption of Accounting Standards Update 2021-08, Business Combinations (Topic 805) during the three months ended March 31, 2022. The financial results of Oasis Midstream’s Williston Basin operations are included in our gathering and processing north segment and Oasis Midstream’s Delaware Basin operations are included in our gathering and processing south segment from the date of acquisition. During the three months ended March 31, 2022, we recognized approximately $17 million of transaction costs related to the Merger, which are included in general and administrative expenses in our consolidated statements of operations. The purchase price has been allocated to the assets acquired and liabilities assumed based on preliminary fair values. Certain preliminary fair values are Level 3 fair value measurements and were developed by management with the assistance of a third-party valuation firm. We estimated the fair value of the senior notes assumed based on quoted market prices for similar issuances which are considered Level 2 fair value measurements. The preliminary fair values were estimated primarily utilizing market related information and other projections on the performance of the assets acquired, including an analysis of discounted cash flows at a discount rate of approximately 12%. The preliminary fair values of property, plant and equipment, intangible assets and goodwill and their allocation to our segments are subject to change pending a final determination of the fair values as more information is received about their respective values. We expect to finalize the purchase price allocation for this transaction in 2022. The following table summarizes the preliminary fair values of the assets acquired and liabilities assumed at the acquisition date (in millions) : Cash $ 14.9 Other current assets 63.4 Property, plant and equipment 1,245.8 Intangible assets 497.0 Total assets acquired 1,821.1 Current liabilities 45.9 Long-term debt (1) 698.7 Other long-term liabilities (2) 25.8 Total liabilities assumed 770.4 Net assets acquired excluding goodwill 1,050.7 Goodwill 39.3 Net assets acquired $ 1,090.0 (1) Consists of approximately $218 million outstanding borrowings under the Oasis Midstream revolver, which was immediately repaid upon the closing of the Merger and approximately $450 million of unsecured senior notes and the related fair value adjustment of approximately $30.7 million. For a further discussion of the long-term debt assumed in conjunction with the Merger, see Note 8. (2) Consists primarily of liabilities for asset retirement obligations of approximately $16.5 million. The identifiable intangible assets primarily consist of customer accounts with Oasis Petroleum and other customers with a weighted-average remaining life of 20 years. The goodwill recognized relates primarily to the anticipated operating synergies between the assets acquired and our existing operations and is reflected in our gathering and processing north segment. Our consolidated statement of operations for three months ended March 31, 2022 include the results of Oasis Midstream since February 1, 2022, the closing date of the Merger. During the three months ended March 31, 2022, we recognized approximately $66.8 million of revenues and $23.5 million of net income related to Oasis Midstream’s operations. The table below presents selected unaudited pro forma information as if the Merger had occurred on January 1, 2021 ( in millions ). The pro forma information is not necessarily indicative of the financial results that would have occurred if the Merger 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 (loss) also includes the net effects of interest expense on incremental borrowings, repayments of long-term debt and amortization of the fair value adjustment to long-term debt. Crestwood Equity Three Months Ended March 31, 2022 2021 Revenues $ 1,618.4 $ 1,133.1 Net income (loss) $ 28.4 $ (15.2) Net income (loss) per limited partner unit: Basic and Diluted $ 0.03 $ (0.37) Crestwood Midstream Three Months Ended March 31, 2022 2021 Revenues $ 1,618.4 $ 1,133.1 Net income (loss) $ 26.4 $ (17.3)

Certain Balance Sheet Informati

Certain Balance Sheet Information	3 Months Ended
	Mar. 31, 2022
Balance Sheet Related Disclosures [Abstract]
Certain Balance Sheet Information	Certain Balance Sheet Information Accrued Expenses and Other Liabilities Accrued expenses and other liabilities consisted of the following ( in millions ): March 31, December 31, 2022 2021 CMLP Accrued expenses $ 50.0 $ 66.3 Accrued property taxes 5.2 4.4 Income tax payable 0.4 0.4 Interest payable 54.7 30.6 Accrued additions to property, plant and equipment 25.6 17.4 Operating leases 10.4 13.2 Finance leases 30.5 1.7 Contract liabilities 11.0 10.7 Asset retirement obligations 1.1 1.4 Total CMLP accrued expenses and other liabilities $ 188.9 $ 146.1 CEQP Accrued expenses 1.2 0.9 Income tax payable 0.2 0.1 Total CEQP accrued expenses and other liabilities $ 190.3 $ 147.1 Other Long-Term Liabilities Other long-term liabilities consisted of the following ( in millions ): March 31, December 31, 2022 2021 CMLP Contract liabilities $ 202.1 $ 187.1 Operating leases 14.5 19.4 Asset retirement obligations 51.7 34.8 Other 13.3 12.8 Total CMLP other long-term liabilities $ 281.6 $ 254.1 CEQP Other 1.5 4.6 Total CEQP other long-term liabilities $ 283.1 $ 258.7

Investments in Unconsolidated A

Investments in Unconsolidated Affiliates	3 Months Ended
	Mar. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Investments in Unconsolidated Affiliates	Investments in Unconsolidated Affiliates Net Investments and Earnings (Loss) of Unconsolidated Affiliates Our net investments in and earnings (loss) from our unconsolidated affiliates are as follows ( in millions ): Investment Earnings (Loss) from Three Months Ended March 31, December 31, March 31, 2022 2021 2022 2021 Crestwood Permian Basin Holdings LLC (1) $ 118.7 $ 116.1 $ 2.6 $ (0.8) Tres Palacios Holdings LLC (2) 42.8 36.2 0.6 9.3 Powder River Basin Industrial Complex, LLC (3) 3.3 3.5 (0.2) 0.1 Stagecoach Gas Services LLC (4) — — — (112.3) Total $ 164.8 $ 155.8 $ 3.0 $ (103.7) (1) As of March 31, 2022, our equity in the underlying net assets of Crestwood Permian Basin Holdings LLC (Crestwood Permian) exceeded our investment balance by $4.6 million, and this excess amount is not subject to amortization. Our Crestwood Permian investment is included in our gathering and processing south segment. (2) As of March 31, 2022, our equity in the underlying net assets of Tres Palacios Holdings LLC (Tres Holdings) exceeded the carrying value of our investment balance by approximately $21.2 million. During both the three months ended March 31, 2022 and 2021, we recorded amortization of approximately $0.3 million related to this excess basis, which is reflected as an increase in our earnings from unconsolidated affiliates in our consolidated statements of operations. Our Tres Holdings investment is included in our storage and logistics segment. (3) As of March 31, 2022, our equity in the underlying net assets of Powder River Basin Industrial Complex, LLC (PRBIC) approximates the carrying value of our investment balance. Our PRBIC investment is included in our storage and logistics segment. (4) In 2021, we sold our 50% equity interest in our Stagecoach Gas Services LLC (Stagecoach Gas) equity investment to a subsidiary of Kinder Morgan, Inc. During the first quarter of 2021, we recorded our share of a goodwill impairment recorded by Stagecoach Gas based on market-based information received by Stagecoach Gas from Con Edison Gas Pipeline and Storage Northeast, LLC’s (the previous owner of the other 50% equity interest in Stagecoach Gas) strategic evaluation of its investment during the three months ended March 31, 2021. This resulted in a $119.9 million reduction in our earnings from unconsolidated affiliates during the three months ended March 31, 2021. Our Stagecoach Gas investment was previously included in our storage and logistics segment. Distributions and Contributions The following table summarizes our distributions from and contributions to our unconsolidated affiliates (in millions) : Distributions (1) Contributions Three Months Ended Three Months Ended March 31, March 31, 2022 2021 2022 2021 Crestwood Permian $ 8.5 $ 3.3 $ 8.5 $ 3.3 Tres Holdings — — 6.0 6.9 PRBIC — 0.1 — — Stagecoach Gas — 14.0 — — Total $ 8.5 $ 17.4 $ 14.5 $ 10.2

Risk Management

Risk Management	3 Months Ended
	Mar. 31, 2022
Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]
Risk Management	Risk ManagementWe 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 7. 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 the 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 ( in millions ): Three Months Ended March 31, 2022 2021 Product revenues $ 202.2 $ 114.8 Loss reflected in product costs $ (47.6) $ (8.1) 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: March 31, 2022 December 31, 2021 Fixed Price Fixed Price Fixed Price Fixed Price Propane, ethane, butane, heating oil and crude oil (MMBbls) 57.9 60.1 71.6 75.8 Natural gas (Bcf) 24.3 36.2 31.9 43.4 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 36 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 ): March 31, 2022 December 31, 2021 Aggregate fair value liability of derivative instruments with credit-risk-related contingent features (1) $ 71.6 $ 57.9 Broker-related net derivative asset position $ 87.7 $ 104.8 Broker-related cash collateral received $ 68.7 $ 76.8 Cash collateral (paid) received, net $ (6.8) $ 11.4

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2022
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 March 31, 2022 and December 31, 2021, 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 New York Mercantile Exchange 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 March 31, 2022 and December 31, 2021 ( in millions ): March 31, 2022 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 $ 53.3 $ 856.4 $ — $ 909.7 $ (816.5) $ (67.7) $ 25.5 Other investments (2) 2.5 — — 2.5 — — 2.5 Total assets at fair value $ 55.8 $ 856.4 $ — $ 912.2 $ (816.5) $ (67.7) $ 28.0 Liabilities Liabilities from price risk management $ 62.3 $ 867.6 $ — $ 929.9 $ (816.5) $ (5.8) $ 107.6 Total liabilities at fair value $ 62.3 $ 867.6 $ — $ 929.9 $ (816.5) $ (5.8) $ 107.6 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 (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 March 31, 2022 and December 31, 2021, 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 March 31, 2022 and December 31, 2021, 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 ): March 31, 2022 December 31, 2021 Carrying Fair Carrying Fair 2025 Senior Notes $ 496.8 $ 503.8 $ 496.5 $ 511.9 2027 Senior Notes $ 594.5 $ 595.1 $ 594.2 $ 615.0 February 2029 Senior Notes $ 691.2 $ 699.7 $ 690.8 $ 727.3 April 2029 Senior Notes (1) $ 480.0 $ 480.3 $ — $ — (1) Represents $450 million of unsecured senior notes assumed in conjunction with the merger with Oasis Midstream discussed in Note 3, and the related net fair value adjustment which are further described in Note 8.

Long-Term Debt

Long-Term Debt	3 Months Ended
	Mar. 31, 2022
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt consisted of the following at March 31, 2022 and December 31, 2021 ( in millions ): March 31, December 31, Credit Facility $ 560.0 $ 282.0 2025 Senior Notes 500.0 500.0 2027 Senior Notes 600.0 600.0 February 2029 Senior Notes 700.0 700.0 April 2029 Senior Notes 450.0 — April 2029 Senior Notes fair value adjustment, net 30.0 — Other (1) 0.2 0.2 Less: deferred financing costs, net 30.1 29.9 Total debt 2,810.1 2,052.3 Less: current portion 0.2 0.2 Total long-term debt, less current portion $ 2,809.9 $ 2,052.1 (1) Represents non-interest bearing obligations related to certain companies acquired in 2014 with payments due through 2022. Credit Facility Crestwood Midstream’s five-year $1.5 billion revolving credit facility (the CMLP Credit Facility) is available to fund acquisitions, working capital and internal growth projects and for general partnership purposes. In conjunction with the merger with Oasis Midstream on February 1, 2022, we borrowed amounts under the CMLP Credit Facility to fund the cash paid of $160 million to Oasis Petroleum and to repay approximately $218 million of borrowings on Oasis Midstream’s credit facility, which was retired on February 1, 2022. 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 March 31, 2022, the net debt to consolidated EBITDA ratio was approximately 3.48 to 1.0, the consolidated EBITDA to consolidated interest expense ratio was approximately 5.04 to 1.0, and the senior secured leverage ratio was 0.69 to 1.0. At March 31, 2022, Crestwood Midstream had $931.2 million of available capacity under its credit facility considering the most restrictive debt covenants in its credit agreement. At March 31, 2022 and December 31, 2021, Crestwood Midstream’s outstanding standby letters of credit were $8.8 million and $6.3 million. Borrowings under the credit facility accrue interest at either prime or the Adjusted Term SOFR (as defined in the credit agreement) plus applicable spreads, which resulted in interest rates between 2.07% and 4.00% at March 31, 2022 and 1.90% and 4.00% at December 31, 2021. The weighted-average interest rate on outstanding borrowings as of March 31, 2022 and December 31, 2021 was 2.16% and 1.91%. Senior Notes February 2029 Senior Notes. In January 2021, Crestwood Midstream issued $700 million of 6.00% unsecured senior notes due 2029 (the February 2029 Senior Notes). The February 2029 Senior Notes will mature on February 1, 2029, and interest is payable semi-annually 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 our senior notes that were due in 2023 and to repay indebtedness under the CMLP Credit Facility. April 2029 Senior Notes. In February 2022, in conjunction with the merger with Oasis Midstream, we assumed $450 million of 8.00% unsecured senior notes due 2029 (the April 2029 Senior Notes) and we recorded a fair value adjustment of approximately $30.7 million related to the senior notes. During the three months ended March 31, 2022, we recorded a reduction to our interest and debt expense of approximately $0.7 million related to the amortization of the fair value adjustment. The April 2029 Senior Notes will mature on April 1, 2029, and interest is payable semi-annually on April 1 and October 1 of each year. 2023 Senior Note Repayments . In January 2021, we utilized a portion of the proceeds from the issuance of the 2029 Senior Notes to repurchase and cancel approximately $399.2 million of principal outstanding under our senior notes that were due in 2023. In conjunction with the repayment of the notes, we recognized a loss on extinguishment of debt of approximately $5.5 million. During 2021, we repaid all amounts outstanding under our senior notes due 2023.

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2022
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 was seeking to block the parties from closing the merger and in the alternative, to revise the Registration Statement and award the plaintiff attorney’s and expert’s fees. The Plaintiff was unsuccessful as the merger was completed and the lawsuit was dismissed. 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. Since the lawsuit was filed, we have paid Linde approximately $22.7 million (including approximately $3.2 million paid during the three months ended March 31, 2022) related to this matter, and Linde claims remaining unpaid invoices of approximately $33 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 March 31, 2022 and December 31, 2021, we had approximately $16.6 million and $16.8 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. At March 31, 2022 and December 31, 2021, our accrual of approximately $0.9 million and $1.0 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 $0.9 million to $1.8 million at March 31, 2022. 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 March 31, December 31, 2021 March 31, December 31, 2021 Self-insurance reserves (1) $ 5.9 $ 5.5 $ 4.9 $ 4.7 (1) At March 31, 2022, 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. Guarantees and Indemnifications We periodically provide indemnification arrangements related to assets or businesses we have sold. Our potential exposure under indemnification arrangements can range from a specified amount to an unlimited amount, depending on the nature of the claim, specificity as to duration, and the particular transaction. As of March 31, 2022 and December 31, 2021, we have no amounts accrued for these indemnifications.

Leases

Leases	3 Months Ended
	Mar. 31, 2022
Leases [Abstract]
Leases	Leases The following table summarizes the balance sheet information related to our operating and finance leases (in millions ): March 31, December 31, 2021 Operating Leases Operating lease right-of-use assets, net $ 20.3 $ 27.4 Accrued expenses and other liabilities $ 10.4 $ 13.2 Other long-term liabilities 14.5 19.4 Total operating lease liabilities $ 24.9 $ 32.6 Finance Leases Property, plant and equipment $ 13.4 $ 12.3 Less: accumulated depreciation 10.0 9.2 Property, plant and equipment, net $ 3.4 $ 3.1 Accrued expenses and other liabilities $ 30.5 $ 1.7 Other long-term liabilities 1.5 1.2 Total finance lease liabilities $ 32.0 $ 2.9 Lease expense. Our operating lease expense, net totaled $3.5 million and $4.8 million for the three months ended March 31, 2022 and 2021. Our finance lease expense totaled $0.9 million for both the three months ended March 31, 2022 and 2021. Other. During March 2022, we exercised an option to purchase crude oil railcars under certain of our operating leases as a result of our plan to exit our crude oil railcar operations. In April 2022, we entered into an agreement with a third party to sell the crude oil railcars purchased under the operating lease and, as a result, we reclassified approximately $24.7 million of these assets as current assets held for sale, which is included in prepaid expenses and other current assets on our consolidated balance sheet at March 31, 2022. The current assets held for sale were recorded at fair value based on the anticipated sale proceeds, which is a Level 3 fair value measurement. At March 31, 2022, we also reclassified approximately $28.7 million of operating lease right-of-use liabilities associated with these assets to finance lease right-of-use liabilities, which is included in accrued expenses and other liabilities on our consolidated balance sheet. During the three months ended March 31, 2022, we recorded a loss on long-lived assets of approximately $4.0 million for the difference between the assets held for sale and the carrying value of the assets to be sold.
Lessee, Finance Leases	Leases The following table summarizes the balance sheet information related to our operating and finance leases (in millions ): March 31, December 31, 2021 Operating Leases Operating lease right-of-use assets, net $ 20.3 $ 27.4 Accrued expenses and other liabilities $ 10.4 $ 13.2 Other long-term liabilities 14.5 19.4 Total operating lease liabilities $ 24.9 $ 32.6 Finance Leases Property, plant and equipment $ 13.4 $ 12.3 Less: accumulated depreciation 10.0 9.2 Property, plant and equipment, net $ 3.4 $ 3.1 Accrued expenses and other liabilities $ 30.5 $ 1.7 Other long-term liabilities 1.5 1.2 Total finance lease liabilities $ 32.0 $ 2.9 Lease expense. Our operating lease expense, net totaled $3.5 million and $4.8 million for the three months ended March 31, 2022 and 2021. Our finance lease expense totaled $0.9 million for both the three months ended March 31, 2022 and 2021. Other. During March 2022, we exercised an option to purchase crude oil railcars under certain of our operating leases as a result of our plan to exit our crude oil railcar operations. In April 2022, we entered into an agreement with a third party to sell the crude oil railcars purchased under the operating lease and, as a result, we reclassified approximately $24.7 million of these assets as current assets held for sale, which is included in prepaid expenses and other current assets on our consolidated balance sheet at March 31, 2022. The current assets held for sale were recorded at fair value based on the anticipated sale proceeds, which is a Level 3 fair value measurement. At March 31, 2022, we also reclassified approximately $28.7 million of operating lease right-of-use liabilities associated with these assets to finance lease right-of-use liabilities, which is included in accrued expenses and other liabilities on our consolidated balance sheet. During the three months ended March 31, 2022, we recorded a loss on long-lived assets of approximately $4.0 million for the difference between the assets held for sale and the carrying value of the assets to be sold.

Partners' Capital

Partners' Capital	3 Months Ended
	Mar. 31, 2022
Statement of Partners' Capital [Abstract]
Partners' Capital	Partners’ Capital and Non-Controlling Partner Common and Subordinated Units On February 1, 2022, we completed the merger with Oasis Midstream. Pursuant to the merger agreement, Oasis Petroleum received cash plus approximately 20.9 million newly issued CEQP units in exchange for its 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 Oasis Midstream common units held by them. For a further discussion of the merger with Oasis Midstream, see Note 3. In March 2021, CEQP acquired approximately 11.5 million CEQP common units and 0.4 million subordinated units of CEQP from Crestwood Holdings LLC (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 three months ended March 31, 2021. This transaction resulted in CEQP retiring the common and subordinated units acquired from Crestwood Holdings. In addition, in conjunction with this transaction, CEQP eliminated approximately $2.6 million of accounts payable to Crestwood Holdings which is reflected as an increase to CEQP’s common unitholders’ partners capital in its consolidated statements of partners capital during the three months ended March 31, 2021. Transaction costs related to this transaction 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 three months ended March 31, 2021. Distributions Crestwood Equity Limited Partners. A summary of CEQP’s limited partner quarterly cash distributions for the three months ended March 31, 2022 and 2021 is presented below: Record Date Payment Date Per Unit Rate Cash Distributions ( in millions ) 2022 February 7, 2022 February 14, 2022 $ 0.625 $ 60.9 2021 February 5, 2021 February 12, 2021 $ 0.625 $ 46.4 On April 14, 2022, we declared a distribution of $0.655 per limited partner unit to be paid on May 13, 2022 to unitholders of record on May 6, 2022 with respect to the quarter ended March 31, 2022. Preferred Unitholders . During the three months ended March 31, 2022 and 2021, we paid cash distributions to our preferred unitholders of approximately $15 million in both periods. On April 14, 2022, the board of directors of our general partner authorized a cash distribution to our preferred unitholders of approximately $15 million with respect to the quarter ended March 31, 2022. Crestwood Midstream During the three months ended March 31, 2022 and 2021, Crestwood Midstream paid cash distributions of $238.1 million and $334.0 million to its partners. On February 1, 2022, Crestwood Midstream received a non-cash contribution of approximately $1,075.1 million from Crestwood Equity related to net assets it acquired in conjunction with the merger with Oasis Midstream. In addition, on February 1, 2022, Crestwood Equity contributed cash acquired in conjunction with the merger with Oasis Midstream of approximately $14.9 million to Crestwood Midstream. Non-Controlling Partner Crestwood Niobrara issued preferred interests to CN Jackalope Holdings LLC (Jackalope Holdings), which are reflected as non-controlling interest in subsidiary apart from partners’ capital (i.e., temporary equity) on our consolidated balance sheets. We adjust the carrying amount of our non-controlling interest to its redemption value each period through net income attributable to non-controlling partner. The following table shows the change in our non-controlling interest in subsidiary at March 31, 2022 and 2021 (in millions) : Balance at December 31, 2021 $ 434.6 Distributions to non-controlling partner (10.3) Net income attributable to non-controlling partner 10.2 Balance at March 31, 2022 $ 434.5 Balance at December 31, 2020 $ 432.7 Distributions to non-controlling partner (9.3) Net income attributable to non-controlling partner 10.1 Balance at March 31, 2021 $ 433.5 In April 2022, Crestwood Niobrara paid cash distributions to Jackalope Holdings of approximately $10.3 million for the quarter ended March 31, 2022. Other In February 2022, Crestwood Equity issued 177,025 performance units under the Crestwood Equity Partners LP Long Term Incentive Plan (Crestwood LTIP). The performance units 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. As of March 31, 2022, we had total unamortized compensation expense of approximately $4.6 million related to these performance units. During the three months ended March 31, 2022, we recognized compensation expense of $0.2 million related to these performance units, which is included in general and administrative expenses on our consolidated statements of operations. During the three months ended March 31, 2022, 206,017 performance units that were previously issued under the Crestwood LTIP vested, and as a result of the attainment of certain performance and market goals and related distributions during the three years that the awards were outstanding, we issued 526,322 common units during the three months ended March 31, 2022 related to those performance units.

Earnings Per Limited Partner Un

Earnings Per Limited Partner Unit	3 Months Ended
	Mar. 31, 2022
Earnings Per Share [Abstract]
Earnings Per Limited Partner Unit	Earnings Per Limited Partner Unit We calculate the dilutive effect of the preferred units and Crestwood Niobrara preferred units 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. The dilutive effect of the stock-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. 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 three months ended March 31, 2022 and 2021 (in millions) : Three Months Ended March 31, 2022 2021 Preferred units (1) 7.1 7.1 Crestwood Niobrara’s preferred units (1) 3.6 4.2 Unit-based compensation performance units (1) 0.3 0.1 Subordinated units (2) — 0.4 (1) For additional information regarding the potential conversion/redemption of our preferred units and Crestwood Niobrara’s preferred units to CEQP common units, and of our performance units, see our 2021 Annual Report on Form 10-K. (2) In March 2021, CEQP retired the subordinated units. For additional information regarding the retirement of the subordinated units, see Note 11.

Segments

Segments	3 Months Ended
	Mar. 31, 2022
Segment Reporting [Abstract]
Segments	SegmentsIn conjunction with the divestiture of our Stagecoach Gas equity method investment as discussed in Note 5 and the merger with Oasis Midstream as discussed in Note 3, 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, Jackalope and Oasis Midstream Williston operations); (ii) gathering and processing south operations (includes our Marcellus, Barnett and Oasis Midstream Delaware Basin 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 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 NGLs, crude oil and natural gas storage, terminal, marketing and transportation (including rail, truck and pipeline) services to producers, refiners, marketers, utilities and other customers. Below is a reconciliation of CEQP’s and CMLP’s net loss to EBITDA ( in millions ): CEQP CMLP Three Months Ended Three Months Ended March 31, March 31, 2022 2021 2022 2021 Net income (loss) $ 22.2 $ (38.3) $ 20.2 $ (40.4) Add: Interest and debt expense, net 36.1 36.0 36.1 36.0 Loss on modification/extinguishment of debt — 5.5 — 5.5 Benefit for income taxes — (0.1) — (0.1) Depreciation, amortization and accretion 74.8 59.2 78.2 62.8 EBITDA $ 133.1 $ 62.3 $ 134.5 $ 63.8 The following tables summarize CEQP’s and CMLP’s reportable segment data for the three months ended March 31, 2022 and 2021 ( in millions ). Intersegment revenues included in the following tables are accounted for as arms-length transactions that apply our revenue recognition policy described in our 2021 Annual Report on Form 10-K. Included in earnings (loss) from unconsolidated affiliates, net reflected in the tables below was approximately $4.6 million and $129.4 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 three months ended March 31, 2022 and 2021. Segment EBITDA Information Three Months Ended March 31, 2022 Gathering and Processing North Gathering and Processing South Storage and Logistics Corporate Total Crestwood Midstream Revenues $ 235.2 $ 30.7 $ 1,317.9 $ — $ 1,583.8 Intersegment revenues 127.4 — (127.4) — — Costs of product/services sold 205.6 (0.6) 1,159.4 — 1,364.4 Operations and maintenance expense 23.7 6.7 12.0 — 42.4 General and administrative expense — — — 41.7 41.7 Gain (loss) on long-lived assets, net — 0.2 (4.0) — (3.8) Earnings from unconsolidated affiliates, net — 2.6 0.4 — 3.0 Crestwood Midstream EBITDA $ 133.3 $ 27.4 $ 15.5 $ (41.7) $ 134.5 Crestwood Equity General and administrative expense — — — 1.7 1.7 Other income, net — — — 0.3 0.3 Crestwood Equity EBITDA $ 133.3 $ 27.4 $ 15.5 $ (43.1) $ 133.1 Three Months Ended March 31, 2021 Gathering and Processing North Gathering and Processing South Storage and Logistics Corporate Total Crestwood Midstream Revenues $ 129.8 $ 24.6 $ 878.3 $ — $ 1,032.7 Intersegment revenues 105.3 — (105.3) — — Costs of product/services sold 116.2 0.3 697.3 — 813.8 Operations and maintenance expense 15.1 6.3 11.4 — 32.8 General and administrative expense — — — 17.2 17.2 Gain (loss) on long-lived assets, net (0.2) (1.3) 0.1 — (1.4) Loss from unconsolidated affiliates, net — (0.8) (102.9) — (103.7) Crestwood Midstream EBITDA $ 103.6 $ 15.9 $ (38.5) $ (17.2) $ 63.8 Crestwood Equity General and administrative expense — — — 1.5 1.5 Crestwood Equity EBITDA $ 103.6 $ 15.9 $ (38.5) $ (18.7) $ 62.3 Other Segment Information CEQP CMLP March 31, 2022 December 31, 2021 March 31, 2022 December 31, 2021 Total Assets Gathering and Processing North $ 4,090.1 $ 2,408.0 $ 4,090.1 $ 2,408.0 Gathering and Processing South 1,023.1 886.5 1,150.4 1,017.4 Storage and Logistics 1,097.3 1,125.1 1,097.3 1,125.1 Corporate 29.6 26.1 24.3 20.7 Total Assets $ 6,240.1 $ 4,445.7 $ 6,362.1 $ 4,571.2

Revenues

Revenues	3 Months Ended
	Mar. 31, 2022
Revenue Recognition [Abstract]
Revenues	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 Accounting Standards Update 2014-09, Revenue from Contracts with Customers (Topic 606) totaled $429.8 million and $331.0 million at March 31, 2022 and December 31, 2021, 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) : March 31, 2022 December 31, 2021 Contract assets (non-current) $ 1.2 $ 1.3 Contract liabilities (current) (1) $ 11.0 $ 10.7 Contract liabilities (non-current) (1) $ 202.1 $ 187.1 (1) During the three months ended March 31, 2022, we recognized revenues of approximately $3.5 million that were previously included in contract liabilities at December 31, 2021. The remaining change in our contract liabilities during the three months ended March 31, 2022 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 March 31, 2022 (in millions) : Remainder of 2022 $ 65.8 2023 65.1 2024 44.4 2025 2.6 2026 0.5 Thereafter 1.3 Total $ 179.7 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 three months ended March 31, 2022 and 2021 ( in millions ). 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 represents revenues related to our commodity-based derivatives. Three Months Ended March 31, 2022 Gathering and Processing North Gathering and Processing South Storage and Logistics Intersegment Elimination Total Topic 606 revenues Gathering Natural gas $ 25.9 $ 22.4 $ — $ — $ 48.3 Crude oil 14.8 1.0 — — 15.8 Water 34.7 2.2 — — 36.9 Processing Natural gas 14.4 1.1 — — 15.5 Compression Natural gas — 3.5 — — 3.5 Storage Crude oil 0.5 — — (0.1) 0.4 NGLs — — 2.8 — 2.8 Pipeline Crude oil — — 0.5 — 0.5 Transportation Crude oil 1.2 0.1 — — 1.3 NGLs — — 5.8 — 5.8 Rail Loading Crude oil — — 0.4 — 0.4 Product Sales Natural gas 63.9 0.3 98.7 (52.1) 110.8 Crude oil 128.1 — 374.0 (11.2) 490.9 NGLs 76.9 — 632.7 (64.0) 645.6 Water 1.6 — — — 1.6 Other 0.2 — 0.3 — 0.5 Total Topic 606 revenues 362.2 30.6 1,115.2 (127.4) 1,380.6 Non-Topic 606 revenues 0.4 0.1 202.7 — 203.2 Total revenues $ 362.6 $ 30.7 $ 1,317.9 $ (127.4) $ 1,583.8 Three Months Ended March 31, 2021 Gathering and Processing North Gathering and Processing South Storage and Logistics Intersegment Elimination Total Topic 606 revenues Gathering Natural gas $ 13.2 $ 18.2 $ — $ — $ 31.4 Crude oil 20.7 — — — 20.7 Water 22.0 — — — 22.0 Processing Natural gas 5.8 1.2 — — 7.0 Compression Natural gas — 4.7 — — 4.7 Storage Crude oil 0.1 — 0.2 (0.1) 0.2 NGLs — — 3.7 — 3.7 Pipeline Crude oil — — 0.8 — 0.8 Transportation Crude oil 0.7 — — — 0.7 NGLs — — 4.2 — 4.2 Rail Loading Crude oil — — 1.0 — 1.0 Product Sales Natural gas 42.3 0.5 95.6 (42.2) 96.2 Crude oil 90.0 — 251.2 (22.7) 318.5 NGLs 40.3 — 406.0 (40.3) 406.0 Other — — 0.2 — 0.2 Total Topic 606 revenues 235.1 24.6 762.9 (105.3) 917.3 Non-Topic 606 revenues — — 115.4 — 115.4 Total revenues $ 235.1 $ 24.6 $ 878.3 $ (105.3) $ 1,032.7

Related Party Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2022
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 our strategic transactions with Crestwood Holdings in August 2021, Crestwood Holdings and its affiliates are no longer considered related parties of CEQP and CMLP. During the three months ended March 31, 2021, we paid approximately $0.3 million of capital expenditures to Applied Consultants, Inc., an affiliate of Crestwood Holdings. In addition, during the three months ended March 31, 2021, Crestwood Holdings allocated a $4.6 million reduction of unit-based compensation charges to CEQP and CMLP. Also, CEQP allocated approximately $0.2 million of its general and administrative costs to Crestwood Holdings during the three months ended March 31, 2021. The following table shows transactions with our affiliates which are reflected in our consolidated statements of operations ( in millions ). For a further description of our related party agreements, see our 2021 Annual Report on Form 10-K. Three Months Ended March 31, 2022 2021 Revenues at CEQP and CMLP (1) $ 97.7 $ 4.9 Costs of product/services sold at CEQP and CMLP (2) $ 68.5 $ 41.1 Operations and maintenance expenses at CEQP and CMLP charged to our unconsolidated affiliates (3) $ 4.8 $ 5.7 General and administrative expenses charged by CEQP to CMLP, net (4) $ 7.5 $ 5.9 General and administrative expenses at CEQP and CMLP (5) $ 0.9 $ — (1) Includes (i) $1.6 million and $4.9 million during the three months ended March 31, 2022 and 2021 related to the sale of NGLs to a subsidiary of Crestwood Permian; (ii) $0.5 million during the three months ended March 31, 2022 related to compressor leases with a subsidiary of Crestwood Permian; (iii) $59.0 million during the three months ended March 31, 2022 primarily related to the sale of crude oil and NGLs to a subsidiary of Oasis Petroleum; and (iv) $36.6 million during the three months ended March 31, 2022 primarily related to gathering and processing services under agreements with a subsidiary of Oasis Petroleum. (2) Includes (i) $36.2 million and $30.3 million during the three months ended March 31, 2022 and 2021 related to purchases of natural gas and NGLs from a subsidiary of Crestwood Permian; (ii) $0.9 million and $10.8 million during the three months ended March 31, 2022 and 2021 primarily related to purchases of natural gas from a subsidiary of Tres Holdings; and (iii) $31.4 million during the three months ended March 31, 2022 primarily related to purchases of NGLs from a subsidiary of Oasis Petroleum. (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, and these charges are reflected as a reduction of operations and maintenance expenses in our consolidated statements of operations. During the three months ended March 31, 2022, we charged $1.2 million to Tres Holdings and $3.6 million to Crestwood Permian. During the three months ended March 31, 2021, we charged $1.7 million to Stagecoach Gas, $1.2 million to Tres Holdings, and $2.8 million to Crestwood Permian. (4) Includes $8.6 million and $6.9 million of unit-based compensation charges allocated from CEQP to CMLP during the three months ended March 31, 2022 and 2021. In addition, includes $1.1 million and $1.0 million of CMLP’s general and administrative costs allocated to CEQP during the three months ended March 31, 2022 and 2021. (5) Includes $0.9 million during the three months ended March 31, 2022 of general and administrative expenses related to a transition services agreement with Oasis Petroleum. The following table shows balances with our affiliates which are reflected in our consolidated balance sheets ( in millions ): March 31, December 31, Accounts receivable at CEQP and CMLP $ 60.2 $ 8.2 Accounts payable at CEQP and CMLP $ 16.4 $ 12.0

Basis of Presentation and Sum_2

Basis of Presentation and Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2022
Accounting Policies [Abstract]
Significant Accounting Policies	Significant Accounting Policies There were no material changes in our significant accounting policies from those described in our 2021 Annual Report on Form 10-K.

Acquisition (Tables)

Acquisition (Tables)	3 Months Ended
	Mar. 31, 2022
Business Combination and Asset Acquisition [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table summarizes the preliminary fair values of the assets acquired and liabilities assumed at the acquisition date (in millions) : Cash $ 14.9 Other current assets 63.4 Property, plant and equipment 1,245.8 Intangible assets 497.0 Total assets acquired 1,821.1 Current liabilities 45.9 Long-term debt (1) 698.7 Other long-term liabilities (2) 25.8 Total liabilities assumed 770.4 Net assets acquired excluding goodwill 1,050.7 Goodwill 39.3 Net assets acquired $ 1,090.0 (1) Consists of approximately $218 million outstanding borrowings under the Oasis Midstream revolver, which was immediately repaid upon the closing of the Merger and approximately $450 million of unsecured senior notes and the related fair value adjustment of approximately $30.7 million. For a further discussion of the long-term debt assumed in conjunction with the Merger, see Note 8. (2) Consists primarily of liabilities for asset retirement obligations of approximately $16.5 million.
Business Acquisition, Pro Forma Information	Crestwood Equity Three Months Ended March 31, 2022 2021 Revenues $ 1,618.4 $ 1,133.1 Net income (loss) $ 28.4 $ (15.2) Net income (loss) per limited partner unit: Basic and Diluted $ 0.03 $ (0.37) Crestwood Midstream Three Months Ended March 31, 2022 2021 Revenues $ 1,618.4 $ 1,133.1 Net income (loss) $ 26.4 $ (17.3)

Certain Balance Sheet Informa_2

Certain Balance Sheet Information (Tables)	3 Months Ended
	Mar. 31, 2022
Balance Sheet Related Disclosures [Abstract]
Schedule of Accrued Liabilities	Accrued expenses and other liabilities consisted of the following ( in millions ): March 31, December 31, 2022 2021 CMLP Accrued expenses $ 50.0 $ 66.3 Accrued property taxes 5.2 4.4 Income tax payable 0.4 0.4 Interest payable 54.7 30.6 Accrued additions to property, plant and equipment 25.6 17.4 Operating leases 10.4 13.2 Finance leases 30.5 1.7 Contract liabilities 11.0 10.7 Asset retirement obligations 1.1 1.4 Total CMLP accrued expenses and other liabilities $ 188.9 $ 146.1 CEQP Accrued expenses 1.2 0.9 Income tax payable 0.2 0.1 Total CEQP accrued expenses and other liabilities $ 190.3 $ 147.1
Schedule of Other Long-Term Liabilities	Other long-term liabilities consisted of the following ( in millions ): March 31, December 31, 2022 2021 CMLP Contract liabilities $ 202.1 $ 187.1 Operating leases 14.5 19.4 Asset retirement obligations 51.7 34.8 Other 13.3 12.8 Total CMLP other long-term liabilities $ 281.6 $ 254.1 CEQP Other 1.5 4.6 Total CEQP other long-term liabilities $ 283.1 $ 258.7

Investments in Unconsolidated_2

Investments in Unconsolidated Affiliates (Tables)	3 Months Ended
	Mar. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Net Investments and Earnings (Loss) of Unconsolidated Affiliates Our net investments in and earnings (loss) from our unconsolidated affiliates are as follows ( in millions ): Investment Earnings (Loss) from Three Months Ended March 31, December 31, March 31, 2022 2021 2022 2021 Crestwood Permian Basin Holdings LLC (1) $ 118.7 $ 116.1 $ 2.6 $ (0.8) Tres Palacios Holdings LLC (2) 42.8 36.2 0.6 9.3 Powder River Basin Industrial Complex, LLC (3) 3.3 3.5 (0.2) 0.1 Stagecoach Gas Services LLC (4) — — — (112.3) Total $ 164.8 $ 155.8 $ 3.0 $ (103.7) (1) As of March 31, 2022, our equity in the underlying net assets of Crestwood Permian Basin Holdings LLC (Crestwood Permian) exceeded our investment balance by $4.6 million, and this excess amount is not subject to amortization. Our Crestwood Permian investment is included in our gathering and processing south segment. (2) As of March 31, 2022, our equity in the underlying net assets of Tres Palacios Holdings LLC (Tres Holdings) exceeded the carrying value of our investment balance by approximately $21.2 million. During both the three months ended March 31, 2022 and 2021, we recorded amortization of approximately $0.3 million related to this excess basis, which is reflected as an increase in our earnings from unconsolidated affiliates in our consolidated statements of operations. Our Tres Holdings investment is included in our storage and logistics segment. (3) As of March 31, 2022, our equity in the underlying net assets of Powder River Basin Industrial Complex, LLC (PRBIC) approximates the carrying value of our investment balance. Our PRBIC investment is included in our storage and logistics segment. (4) In 2021, we sold our 50% equity interest in our Stagecoach Gas Services LLC (Stagecoach Gas) equity investment to a subsidiary of Kinder Morgan, Inc. During the first quarter of 2021, we recorded our share of a goodwill impairment recorded by Stagecoach Gas based on market-based information received by Stagecoach Gas from Con Edison Gas Pipeline and Storage Northeast, LLC’s (the previous owner of the other 50% equity interest in Stagecoach Gas) strategic evaluation of its investment during the three months ended March 31, 2021. This resulted in a $119.9 million reduction in our earnings from unconsolidated affiliates during the three months ended March 31, 2021. Our Stagecoach Gas investment was previously included in our storage and logistics segment. Distributions and Contributions The following table summarizes our distributions from and contributions to our unconsolidated affiliates (in millions) : Distributions (1) Contributions Three Months Ended Three Months Ended March 31, March 31, 2022 2021 2022 2021 Crestwood Permian $ 8.5 $ 3.3 $ 8.5 $ 3.3 Tres Holdings — — 6.0 6.9 PRBIC — 0.1 — — Stagecoach Gas — 14.0 — — Total $ 8.5 $ 17.4 $ 14.5 $ 10.2

Risk Management (Tables)

Risk Management (Tables)	3 Months Ended
	Mar. 31, 2022
Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]
Schedule of Derivative Instruments	The following table presents the fair value of our commodity derivative instruments with credit-risk related contingent features and their associated collateral ( in millions ): March 31, 2022 December 31, 2021 Aggregate fair value liability of derivative instruments with credit-risk-related contingent features (1) $ 71.6 $ 57.9 Broker-related net derivative asset position $ 87.7 $ 104.8 Broker-related cash collateral received $ 68.7 $ 76.8 Cash collateral (paid) received, net $ (6.8) $ 11.4
Summary of Commodity-Based Derivatives	The following table summarizes the impact to our consolidated statements of operations related to our commodity-based derivatives ( in millions ): Three Months Ended March 31, 2022 2021 Product revenues $ 202.2 $ 114.8 Loss reflected in product costs $ (47.6) $ (8.1)
Notional Amounts And Terms Of Company's Derivative Financial Instruments	The notional amounts of our derivative financial instruments include the following: March 31, 2022 December 31, 2021 Fixed Price Fixed Price Fixed Price Fixed Price Propane, ethane, butane, heating oil and crude oil (MMBbls) 57.9 60.1 71.6 75.8 Natural gas (Bcf) 24.3 36.2 31.9 43.4

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2022
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 March 31, 2022 and December 31, 2021 ( in millions ): March 31, 2022 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 $ 53.3 $ 856.4 $ — $ 909.7 $ (816.5) $ (67.7) $ 25.5 Other investments (2) 2.5 — — 2.5 — — 2.5 Total assets at fair value $ 55.8 $ 856.4 $ — $ 912.2 $ (816.5) $ (67.7) $ 28.0 Liabilities Liabilities from price risk management $ 62.3 $ 867.6 $ — $ 929.9 $ (816.5) $ (5.8) $ 107.6 Total liabilities at fair value $ 62.3 $ 867.6 $ — $ 929.9 $ (816.5) $ (5.8) $ 107.6 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 (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 ): March 31, 2022 December 31, 2021 Carrying Fair Carrying Fair 2025 Senior Notes $ 496.8 $ 503.8 $ 496.5 $ 511.9 2027 Senior Notes $ 594.5 $ 595.1 $ 594.2 $ 615.0 February 2029 Senior Notes $ 691.2 $ 699.7 $ 690.8 $ 727.3 April 2029 Senior Notes (1) $ 480.0 $ 480.3 $ — $ — (1) Represents $450 million of unsecured senior notes assumed in conjunction with the merger with Oasis Midstream discussed in Note 3, and the related net fair value adjustment which are further described in Note 8.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2022
Debt Disclosure [Abstract]
Components Of Long-Term Debt	Long-term debt consisted of the following at March 31, 2022 and December 31, 2021 ( in millions ): March 31, December 31, Credit Facility $ 560.0 $ 282.0 2025 Senior Notes 500.0 500.0 2027 Senior Notes 600.0 600.0 February 2029 Senior Notes 700.0 700.0 April 2029 Senior Notes 450.0 — April 2029 Senior Notes fair value adjustment, net 30.0 — Other (1) 0.2 0.2 Less: deferred financing costs, net 30.1 29.9 Total debt 2,810.1 2,052.3 Less: current portion 0.2 0.2 Total long-term debt, less current portion $ 2,809.9 $ 2,052.1 (1) Represents non-interest bearing obligations related to certain companies acquired in 2014 with payments due through 2022.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	3 Months Ended
	Mar. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Summary of Self-Insurance Reserves	The following table summarizes CEQP’s and CMLP’s self-insurance reserves ( in millions ): CEQP CMLP March 31, December 31, 2021 March 31, December 31, 2021 Self-insurance reserves (1) $ 5.9 $ 5.5 $ 4.9 $ 4.7 (1) At March 31, 2022, 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.

Leases (Tables)

Leases (Tables)	3 Months Ended
	Mar. 31, 2022
Leases [Abstract]
Summary of Balance Sheet Information Related to Operating and Finance Leases	The following table summarizes the balance sheet information related to our operating and finance leases (in millions ): March 31, December 31, 2021 Operating Leases Operating lease right-of-use assets, net $ 20.3 $ 27.4 Accrued expenses and other liabilities $ 10.4 $ 13.2 Other long-term liabilities 14.5 19.4 Total operating lease liabilities $ 24.9 $ 32.6 Finance Leases Property, plant and equipment $ 13.4 $ 12.3 Less: accumulated depreciation 10.0 9.2 Property, plant and equipment, net $ 3.4 $ 3.1 Accrued expenses and other liabilities $ 30.5 $ 1.7 Other long-term liabilities 1.5 1.2 Total finance lease liabilities $ 32.0 $ 2.9

Partners' Capital (Tables)

Partners' Capital (Tables)	3 Months Ended
	Mar. 31, 2022
Statement of Partners' Capital [Abstract]
Schedule of Distributions Made to Members or Limited Partners, by Distribution	A summary of CEQP’s limited partner quarterly cash distributions for the three months ended March 31, 2022 and 2021 is presented below: Record Date Payment Date Per Unit Rate Cash Distributions ( in millions ) 2022 February 7, 2022 February 14, 2022 $ 0.625 $ 60.9 2021 February 5, 2021 February 12, 2021 $ 0.625 $ 46.4
Summary of Change in Non-Controlling Interest in Subsidiary	The following table shows the change in our non-controlling interest in subsidiary at March 31, 2022 and 2021 (in millions) : Balance at December 31, 2021 $ 434.6 Distributions to non-controlling partner (10.3) Net income attributable to non-controlling partner 10.2 Balance at March 31, 2022 $ 434.5 Balance at December 31, 2020 $ 432.7 Distributions to non-controlling partner (9.3) Net income attributable to non-controlling partner 10.1 Balance at March 31, 2021 $ 433.5

Earnings Per Limited Partner _2

Earnings Per Limited Partner Unit (Tables)	3 Months Ended
	Mar. 31, 2022
Earnings Per Share [Abstract]
Summary of Weighted-Average Units Excluded and Basic and Diluted Limited Partner Units	The following table summarizes information regarding the weighted-average of common units excluded during the three months ended March 31, 2022 and 2021 (in millions) : Three Months Ended March 31, 2022 2021 Preferred units (1) 7.1 7.1 Crestwood Niobrara’s preferred units (1) 3.6 4.2 Unit-based compensation performance units (1) 0.3 0.1 Subordinated units (2) — 0.4 (1) For additional information regarding the potential conversion/redemption of our preferred units and Crestwood Niobrara’s preferred units to CEQP common units, and of our performance units, see our 2021 Annual Report on Form 10-K. (2) In March 2021, CEQP retired the subordinated units. For additional information regarding the retirement of the subordinated units, see Note 11.

Segments (Tables)

Segments (Tables)	3 Months Ended
	Mar. 31, 2022
Segment Reporting, Other Significant Reconciling Item [Line Items]
Reconciliation of Net Income (Loss) to Earnings Before Interest, Taxes, Depreciation and Amortization	Below is a reconciliation of CEQP’s and CMLP’s net loss to EBITDA ( in millions ): CEQP CMLP Three Months Ended Three Months Ended March 31, March 31, 2022 2021 2022 2021 Net income (loss) $ 22.2 $ (38.3) $ 20.2 $ (40.4) Add: Interest and debt expense, net 36.1 36.0 36.1 36.0 Loss on modification/extinguishment of debt — 5.5 — 5.5 Benefit for income taxes — (0.1) — (0.1) Depreciation, amortization and accretion 74.8 59.2 78.2 62.8 EBITDA $ 133.1 $ 62.3 $ 134.5 $ 63.8
Summary Of Segment Information	The following tables summarize CEQP’s and CMLP’s reportable segment data for the three months ended March 31, 2022 and 2021 ( in millions ). Intersegment revenues included in the following tables are accounted for as arms-length transactions that apply our revenue recognition policy described in our 2021 Annual Report on Form 10-K. Included in earnings (loss) from unconsolidated affiliates, net reflected in the tables below was approximately $4.6 million and $129.4 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 three months ended March 31, 2022 and 2021. Segment EBITDA Information Three Months Ended March 31, 2022 Gathering and Processing North Gathering and Processing South Storage and Logistics Corporate Total Crestwood Midstream Revenues $ 235.2 $ 30.7 $ 1,317.9 $ — $ 1,583.8 Intersegment revenues 127.4 — (127.4) — — Costs of product/services sold 205.6 (0.6) 1,159.4 — 1,364.4 Operations and maintenance expense 23.7 6.7 12.0 — 42.4 General and administrative expense — — — 41.7 41.7 Gain (loss) on long-lived assets, net — 0.2 (4.0) — (3.8) Earnings from unconsolidated affiliates, net — 2.6 0.4 — 3.0 Crestwood Midstream EBITDA $ 133.3 $ 27.4 $ 15.5 $ (41.7) $ 134.5 Crestwood Equity General and administrative expense — — — 1.7 1.7 Other income, net — — — 0.3 0.3 Crestwood Equity EBITDA $ 133.3 $ 27.4 $ 15.5 $ (43.1) $ 133.1 Three Months Ended March 31, 2021 Gathering and Processing North Gathering and Processing South Storage and Logistics Corporate Total Crestwood Midstream Revenues $ 129.8 $ 24.6 $ 878.3 $ — $ 1,032.7 Intersegment revenues 105.3 — (105.3) — — Costs of product/services sold 116.2 0.3 697.3 — 813.8 Operations and maintenance expense 15.1 6.3 11.4 — 32.8 General and administrative expense — — — 17.2 17.2 Gain (loss) on long-lived assets, net (0.2) (1.3) 0.1 — (1.4) Loss from unconsolidated affiliates, net — (0.8) (102.9) — (103.7) Crestwood Midstream EBITDA $ 103.6 $ 15.9 $ (38.5) $ (17.2) $ 63.8 Crestwood Equity General and administrative expense — — — 1.5 1.5 Crestwood Equity EBITDA $ 103.6 $ 15.9 $ (38.5) $ (18.7) $ 62.3 Other Segment Information CEQP CMLP March 31, 2022 December 31, 2021 March 31, 2022 December 31, 2021 Total Assets Gathering and Processing North $ 4,090.1 $ 2,408.0 $ 4,090.1 $ 2,408.0 Gathering and Processing South 1,023.1 886.5 1,150.4 1,017.4 Storage and Logistics 1,097.3 1,125.1 1,097.3 1,125.1 Corporate 29.6 26.1 24.3 20.7 Total Assets $ 6,240.1 $ 4,445.7 $ 6,362.1 $ 4,571.2

Revenue Recognition (Tables)

Revenue Recognition (Tables)	3 Months Ended
	Mar. 31, 2022
Revenue Recognition [Abstract]
Contract with Customer, Contract Asset, Contract Liability, and Receivable [Table Text Block]	The following table summarizes our contract assets and contract liabilities (in millions) : March 31, 2022 December 31, 2021 Contract assets (non-current) $ 1.2 $ 1.3 Contract liabilities (current) (1) $ 11.0 $ 10.7 Contract liabilities (non-current) (1) $ 202.1 $ 187.1 (1) During the three months ended March 31, 2022, we recognized revenues of approximately $3.5 million that were previously included in contract liabilities at December 31, 2021. The remaining change in our contract liabilities during the three months ended March 31, 2022 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 [Table Text Block]	The following table summarizes the transaction price allocated to our remaining performance obligations under certain contracts that have not been recognized as of March 31, 2022 (in millions) : Remainder of 2022 $ 65.8 2023 65.1 2024 44.4 2025 2.6 2026 0.5 Thereafter 1.3 Total $ 179.7
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 three months ended March 31, 2022 and 2021 ( in millions ). 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 represents revenues related to our commodity-based derivatives. Three Months Ended March 31, 2022 Gathering and Processing North Gathering and Processing South Storage and Logistics Intersegment Elimination Total Topic 606 revenues Gathering Natural gas $ 25.9 $ 22.4 $ — $ — $ 48.3 Crude oil 14.8 1.0 — — 15.8 Water 34.7 2.2 — — 36.9 Processing Natural gas 14.4 1.1 — — 15.5 Compression Natural gas — 3.5 — — 3.5 Storage Crude oil 0.5 — — (0.1) 0.4 NGLs — — 2.8 — 2.8 Pipeline Crude oil — — 0.5 — 0.5 Transportation Crude oil 1.2 0.1 — — 1.3 NGLs — — 5.8 — 5.8 Rail Loading Crude oil — — 0.4 — 0.4 Product Sales Natural gas 63.9 0.3 98.7 (52.1) 110.8 Crude oil 128.1 — 374.0 (11.2) 490.9 NGLs 76.9 — 632.7 (64.0) 645.6 Water 1.6 — — — 1.6 Other 0.2 — 0.3 — 0.5 Total Topic 606 revenues 362.2 30.6 1,115.2 (127.4) 1,380.6 Non-Topic 606 revenues 0.4 0.1 202.7 — 203.2 Total revenues $ 362.6 $ 30.7 $ 1,317.9 $ (127.4) $ 1,583.8 Three Months Ended March 31, 2021 Gathering and Processing North Gathering and Processing South Storage and Logistics Intersegment Elimination Total Topic 606 revenues Gathering Natural gas $ 13.2 $ 18.2 $ — $ — $ 31.4 Crude oil 20.7 — — — 20.7 Water 22.0 — — — 22.0 Processing Natural gas 5.8 1.2 — — 7.0 Compression Natural gas — 4.7 — — 4.7 Storage Crude oil 0.1 — 0.2 (0.1) 0.2 NGLs — — 3.7 — 3.7 Pipeline Crude oil — — 0.8 — 0.8 Transportation Crude oil 0.7 — — — 0.7 NGLs — — 4.2 — 4.2 Rail Loading Crude oil — — 1.0 — 1.0 Product Sales Natural gas 42.3 0.5 95.6 (42.2) 96.2 Crude oil 90.0 — 251.2 (22.7) 318.5 NGLs 40.3 — 406.0 (40.3) 406.0 Other — — 0.2 — 0.2 Total Topic 606 revenues 235.1 24.6 762.9 (105.3) 917.3 Non-Topic 606 revenues — — 115.4 — 115.4 Total revenues $ 235.1 $ 24.6 $ 878.3 $ (105.3) $ 1,032.7

Related Party Transactions (Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2022
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 ( in millions ). For a further description of our related party agreements, see our 2021 Annual Report on Form 10-K. Three Months Ended March 31, 2022 2021 Revenues at CEQP and CMLP (1) $ 97.7 $ 4.9 Costs of product/services sold at CEQP and CMLP (2) $ 68.5 $ 41.1 Operations and maintenance expenses at CEQP and CMLP charged to our unconsolidated affiliates (3) $ 4.8 $ 5.7 General and administrative expenses charged by CEQP to CMLP, net (4) $ 7.5 $ 5.9 General and administrative expenses at CEQP and CMLP (5) $ 0.9 $ — (1) Includes (i) $1.6 million and $4.9 million during the three months ended March 31, 2022 and 2021 related to the sale of NGLs to a subsidiary of Crestwood Permian; (ii) $0.5 million during the three months ended March 31, 2022 related to compressor leases with a subsidiary of Crestwood Permian; (iii) $59.0 million during the three months ended March 31, 2022 primarily related to the sale of crude oil and NGLs to a subsidiary of Oasis Petroleum; and (iv) $36.6 million during the three months ended March 31, 2022 primarily related to gathering and processing services under agreements with a subsidiary of Oasis Petroleum. (2) Includes (i) $36.2 million and $30.3 million during the three months ended March 31, 2022 and 2021 related to purchases of natural gas and NGLs from a subsidiary of Crestwood Permian; (ii) $0.9 million and $10.8 million during the three months ended March 31, 2022 and 2021 primarily related to purchases of natural gas from a subsidiary of Tres Holdings; and (iii) $31.4 million during the three months ended March 31, 2022 primarily related to purchases of NGLs from a subsidiary of Oasis Petroleum. (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, and these charges are reflected as a reduction of operations and maintenance expenses in our consolidated statements of operations. During the three months ended March 31, 2022, we charged $1.2 million to Tres Holdings and $3.6 million to Crestwood Permian. During the three months ended March 31, 2021, we charged $1.7 million to Stagecoach Gas, $1.2 million to Tres Holdings, and $2.8 million to Crestwood Permian. (4) Includes $8.6 million and $6.9 million of unit-based compensation charges allocated from CEQP to CMLP during the three months ended March 31, 2022 and 2021. In addition, includes $1.1 million and $1.0 million of CMLP’s general and administrative costs allocated to CEQP during the three months ended March 31, 2022 and 2021.
Schedule of Related Party Receivables and Payables	The following table shows balances with our affiliates which are reflected in our consolidated balance sheets ( in millions ): March 31, December 31, Accounts receivable at CEQP and CMLP $ 60.2 $ 8.2 Accounts payable at CEQP and CMLP $ 16.4 $ 12.0

Organization and Business Des_2

Organization and Business Description (Details) - Crestwood Midstream Partners LP	3 Months Ended
	Mar. 31, 2022
Crestwood Equity Partners LP
Partnership Organization And Basis Of Presentation [Line Items]
Partnership interest	99.90%
Crestwood Gas Services GP, LLC
Partnership Organization And Basis Of Presentation [Line Items]
Partnership interest	0.10%

Acquisitions (Details)

Acquisitions (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	Feb. 01, 2022	Mar. 31, 2022	Mar. 31, 2021	Feb. 28, 2022	Dec. 31, 2021
Business Acquisition [Line Items]
Goodwill		$ 177.9			$ 138.6
Revenues		1,583.8	$ 1,032.7
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest		22.2	(38.3)
Crestwood Midstream Partners LP
Business Acquisition [Line Items]
Goodwill		177.9			$ 138.6
Revenues		1,583.8	1,032.7
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest		20.2	(40.4)
Valuation Technique, Discounted Cash Flow
Business Acquisition [Line Items]
Business Combination Discount Rate				12.00%
Oasis Midstream Partners LP
Business Acquisition [Line Items]
Cash payment	$ 160
Business Acquisition, Transaction Costs		17
Cash	14.9
Other current assets	63.4
Property, plant and equipment	1,245.8
Intangible assets	497
Total assets acquired	1,821.1
Current liabilities	45.9
Long-term debt	698.7
Other long-term liabilities	25.8
Total liabilities assumed	770.4
Net assets acquired excluding goodwill	1,050.7
Goodwill	39.3
Net assets acquired	$ 1,090
Revenues		66.8
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest		23.5
Business Acquisition, Pro Forma Revenue		1,618.4	1,133.1
Business Acquisition, Pro Forma Net Income (Loss)		$ 28.4	$ (15.2)
Business Acquisition, Pro Forma Earnings Per Share, Diluted		$ 0.03	$ (370,000)
Business Acquisition, Pro Forma Earnings Per Share, Basic		$ 0.03	$ (370,000)
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	20 years
Debt Instrument, Fair Value Adjustment	$ 30.7			$ 30.7
Asset Retirement Obligation	16.5
Consideration transferred	1,800
Oasis Midstream Partners LP | Revolving Credit Facility
Business Acquisition [Line Items]
Credit Facility	218
Oasis Midstream Partners LP | Crestwood Midstream Partners LP
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue		$ 1,618.4	$ 1,133.1
Business Acquisition, Pro Forma Net Income (Loss)		$ 26.4	$ (17.3)
Oasis Midstream Partners LP | Oasis Petroleum Inc.
Business Acquisition [Line Items]
Cash payment	$ 150
Issued shares (in shares)	20,900
Stock exchanged (in shares)	33,800
Oasis Midstream Partners LP | Oasis Midstream Partners LP
Business Acquisition [Line Items]
Stock exchanged (in shares)	14,800
Oasis Midstream Partners LP | Oasis Midstream Public Unitholders
Business Acquisition [Line Items]
Issued shares (in shares)	12,900
Oasis Midstream Partners LP | Oasis Petroleum General Partners
Business Acquisition [Line Items]
Cash payment	$ 10

Certain Balance Sheet Informa_3

Certain Balance Sheet Information (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Accrued Expenses and Other Liabilities [Line Items]
Operating leases	$ 10.4	$ 13.2
Finance leases	30.5	1.7
Contract liabilities	11	10.7
Total CMLP accrued expenses and other liabilities	190.3	147.1
Contract liabilities	202.1	187.1
Operating leases	14.5	19.4
Other long-term liabilities	283.1	258.7
Crestwood Midstream Partners LP
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	50	66.3
Accrued property taxes	5.2	4.4
Income tax payable	0.4	0.4
Interest payable	54.7	30.6
Accrued additions to property, plant and equipment	25.6	17.4
Operating leases	10.4	13.2
Finance leases	30.5	1.7
Contract liabilities	11	10.7
Asset retirement obligations	1.1	1.4
Total CMLP accrued expenses and other liabilities	188.9	146.1
Contract liabilities	202.1	187.1
Operating leases	14.5	19.4
Asset retirement obligations	51.7	34.8
Other long-term liabilities	281.6	254.1
Crestwood Midstream Partners LP | Other
Accrued Expenses and Other Liabilities [Line Items]
Other long-term liabilities	13.3	12.8
Crestwood Equity Partners LP
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	1.2	0.9
Income tax payable	0.2	0.1
Total CMLP accrued expenses and other liabilities	190.3	147.1
Other long-term liabilities	283.1	258.7
Crestwood Equity Partners LP | Other
Accrued Expenses and Other Liabilities [Line Items]
Other long-term liabilities	$ 1.5	$ 4.6

Investments in Unconsolidated_3

Investments in Unconsolidated Affiliates (Net Investments In and Earnings (Loss) from Unconsolidated Affiliates) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Schedule of Equity Method Investments [Line Items]
Investment	$ 164.8		$ 155.8
Earnings (loss) from unconsolidated affiliates, net	3	$ (103.7)
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investment	118.7		116.1
Earnings (loss) from unconsolidated affiliates, net	2.6	(0.8)
Difference between carrying amount and underlying equity	4.6
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investment	42.8		36.2
Earnings (loss) from unconsolidated affiliates, net	0.6	9.3
Difference between carrying amount and underlying equity	21.2
Amortization	0.3	0.3
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Investment	3.3		3.5
Earnings (loss) from unconsolidated affiliates, net	(0.2)	0.1
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Investment	0		$ 0
Earnings (loss) from unconsolidated affiliates, net	$ 0	$ (112.3)
Ownership percentage		50.00%	50.00%
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		$ 119.9

Investments in Unconsolidated_4

Investments in Unconsolidated Affiliates (Distributions and Contributions) (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Apr. 30, 2022	Mar. 31, 2022	Mar. 31, 2021
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		$ 8.5	$ 17.4
Payments to acquire equity method investments		14.5	10.2
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		8.5	3.3
Payments to acquire equity method investments		8.5	3.3
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		0	0
Payments to acquire equity method investments		6	6.9
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		0	0.1
Payments to acquire equity method investments		0	0
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		0	14
Payments to acquire equity method investments		$ 0	$ 0
Subsequent Event | Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments	$ 5.1
Subsequent Event | Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments	$ 1.4

Risk Management (Risk Managemen

Risk Management (Risk Management Activities) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Product revenues	$ 202.2	$ 114.8
Commodity contract
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative instruments not designated as hedging	$ (47.6)	$ (8.1)

Risk Management (Notional Amoun

Risk Management (Notional Amounts and Terms of Company's Derivative Financial Instruments) (Details) bcf in Millions, MMBbls in Millions	Mar. 31, 2022MMBblsbcf	Dec. 31, 2021bcfMMBbls
Propane, ethane, butane, heating oil and crude oil (MMBbls) | Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount | MMBbls	57.9	71.6
Propane, ethane, butane, heating oil and crude oil (MMBbls) | Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount | MMBbls	60.1	75.8
Natural gas (Bcf) | Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount | bcf	24.3	31.9
Natural gas (Bcf) | Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount | bcf	36.2	43.4

Risk Management (Schedule of De

Risk Management (Schedule of Derivative Instruments in Statement of Financial Position, Fair Value) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Derivative [Line Items]
Collateral posted for commodity derivative instruments	$ (6.8)	$ (11.4)
Commodity contract
Derivative [Line Items]
Collateral posted for commodity derivative instruments	(11.6)	(1.5)
Commodity contract with credit contingent features
Derivative [Line Items]
Aggregate fair value of commodity derivative instruments	71.6	57.9
Variation Margin-Related Net Derivative Asset Position
Derivative [Line Items]
Derivative Asset	87.7	104.8
Variation Margin-Related Cash Collateral Received
Derivative [Line Items]
NYMEX margin deposits	$ 68.7	$ 76.8

Risk Management (Narrative) (De

Risk Management (Narrative) (Details) - Price Risk Contracts Member - Maximum	3 Months Ended
	Mar. 31, 2022
Derivative [Line Items]
Remaining maturity	36 months
Percent of contracts expiring in the 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	Mar. 31, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	$ 909.7	$ 728.9
SPH units	2.5	2.2
Assets, Fair Value Disclosure, Excluding Netting Adjustments	912.2	731.1
Netting agreements	(816.5)	(607.4)
Assets, Collateral/Margin Received or Paid	(67.7)	(79.4)
Assets from price risk management, total	25.5	42.1
Total assets at fair value	28	44.3
Liabilities from price risk management	929.9	713.2
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	929.9	713.2
Netting agreements	(816.5)	(607.4)
Liabilities, Collateral/Margin Received or Paid	(5.8)	(8.8)
Liabilities from price risk management, total	107.6	114.6
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	53.3	33.3
SPH units	2.5	2.2
Assets, Fair Value Disclosure, Excluding Netting Adjustments	55.8	35.5
Liabilities from price risk management	62.3	26.9
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	62.3	26.9
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	856.4	695.6
SPH units	0	0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	856.4	695.6
Liabilities from price risk management	867.6	686.3
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	867.6	686.3
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	0	0
SPH units	0	0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	0	0
Liabilities from price risk management	0	0
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	$ 0	$ 0

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule of Carrying Values and Estimated Fair Values of Senior Notes) (Details) - Crestwood Midstream Partners LP - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
2025 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	$ 496.8	$ 496.5
Fair Value	503.8	511.9
2027 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	594.5	594.2
Fair Value	595.1	615
February 2029 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	691.2	690.8
Fair Value	699.7	727.3
April 2029 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	480	0
Fair Value	$ 480.3	$ 0

Long-Term Debt (Components Of L

Long-Term Debt (Components Of Long-Term Debt) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Feb. 28, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Less: deferred financing costs, net	$ 30.1		$ 29.9
Total debt	2,810.1		2,052.3
Less: current portion	0.2		0.2
Total long-term debt, less current portion	2,809.9		2,052.1
April 2029 Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Fair Value Adjustment	30		0
Senior Notes | 2025 Senior Notes
Debt Instrument [Line Items]
Senior notes	500		500
Senior Notes | 2027 Senior Notes
Debt Instrument [Line Items]
Senior notes	600		600
Senior Notes | February 2029 Senior Notes
Debt Instrument [Line Items]
Senior notes	700		700
Senior Notes | April 2029 Senior Notes
Debt Instrument [Line Items]
Senior notes	450	$ 450	0
Other(1)
Debt Instrument [Line Items]
Other(1)	0.2		0.2
Revolving Credit Facility | Crestwood Midstream Revolver
Debt Instrument [Line Items]
Credit Facility	$ 560		$ 282

Long-Term Debt (Narrative) (Det

Long-Term Debt (Narrative) (Details)	Feb. 01, 2022USD ($)	Jan. 31, 2021USD ($)	Mar. 31, 2022USD ($)	Mar. 31, 2021USD ($)	Feb. 28, 2022USD ($)	Dec. 31, 2021USD ($)
Debt Instrument [Line Items]
Debt Instrument, Term			5 years
Senior Secured Leverage Ratio, maximum			3.50
Senior Secured Leverage Ratio			0.69
Extinguishment of Debt, Amount				$ 399,200,000
Loss on modification/extinguishment of debt			$ 0	5,500,000
Amortization of Debt Discount (Premium)			700,000
Oasis Midstream Partners LP
Debt Instrument [Line Items]
Cash payment	$ 160,000,000
Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Loss on modification/extinguishment of debt			0	$ 5,500,000
2027 Senior Notes | Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Senior notes			594,500,000			$ 594,200,000
2025 Senior Notes | Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Senior notes			$ 496,800,000			496,500,000
Crestwood Midstream Revolver
Debt Instrument [Line Items]
Consolidated Leverage Ratio Maximum			5.50
Crestwood Midstream Revolver | Revolving Credit Facility
Debt Instrument [Line Items]
Credit Facility			$ 560,000,000			282,000,000
Available capacity			931,200,000
Letters of credit outstanding			$ 8,800,000			$ 6,300,000
Debt, Weighted Average Interest Rate			2.16%			1.91%
Interest Coverage Ratio Minimum			2.50
Total Funded Debt to Consolidated Ebitda			3.48
Consolidated Ebitda To Consolidated Interest Expense			5.04
Crestwood Midstream Revolver | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate			2.07%			1.90%
Crestwood Midstream Revolver | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate			4.00%			4.00%
Revolving Credit Facility | Oasis Midstream Partners LP
Debt Instrument [Line Items]
Credit Facility	218,000,000
April 2029 Senior Notes | Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Senior notes			$ 480,000,000			$ 0
Oasis Midstream Partners LP | Revolving Credit Facility
Debt Instrument [Line Items]
Credit Facility	218,000,000
Senior Notes | 2027 Senior Notes
Debt Instrument [Line Items]
Senior notes			600,000,000			600,000,000
Senior Notes | 2025 Senior Notes
Debt Instrument [Line Items]
Senior notes			500,000,000			500,000,000
Senior Notes | Senior Notes, due 2029
Debt Instrument [Line Items]
Senior notes		$ 700,000,000
Debt Instrument, Interest Rate, Stated Percentage		6.00%
Proceeds from Issuance of Debt		$ 691,000,000
Senior Notes | April 2029 Senior Notes
Debt Instrument [Line Items]
Senior notes			450,000,000		$ 450,000,000	$ 0
Debt Instrument, Interest Rate, Stated Percentage					8.00%
Senior Notes | April 2029 Senior Notes | Oasis Midstream Partners LP
Debt Instrument [Line Items]
Senior notes	$ 450,000,000
Revolving Loan Facility | Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity			$ 1,500,000,000

Commitments and Contingencies_2

Commitments and Contingencies (Details) - USD ($) $ in Millions	3 Months Ended	27 Months Ended
	Mar. 31, 2022	Mar. 31, 2022	Dec. 31, 2021
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Damages paid	$ 3.2	$ 22.7
Damages	33
Accrued amounts for outstanding legal matters	16.6	16.6	$ 16.8
Crestwood Midstream Partners LP
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Self-insurance reserves	$ 4.9	$ 4.9	$ 4.7

Commitments and Contingencies_3

Commitments and Contingencies (Environmental Compliance) (Details) - Fort Berthold Indian Reservation - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Dec. 31, 2021
Site Contingency [Line Items]
Accrual of environmental loss contingencies	$ 0.9	$ 1
Maximum
Site Contingency [Line Items]
Potential liability for environmental exposures	1.8
Minimum
Site Contingency [Line Items]
Potential liability for environmental exposures	$ 0.9

Commitments and Contingencies_4

Commitments and Contingencies (Self Insurance) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Crestwood Equity Partners LP
Other Commitments [Line Items]
Self-insurance reserves	$ 5.9	$ 5.5
Self-insurance reserves expected to be paid	3.5
Crestwood Midstream Partners LP
Other Commitments [Line Items]
Self-insurance reserves	4.9	$ 4.7
Self-insurance reserves expected to be paid	$ 2.9

Leases (Details)

Leases (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Lessee, Lease, Description [Line Items]
Operating lease right-of-use assets, net	$ 20.3		$ 27.4
Operating leases	10.4		13.2
Operating leases	14.5		19.4
Total operating lease liabilities	24.9		32.6
Finance Lease, Right-of-Use Asset, before Accumulated Amortization	13.4		12.3
Property, plant and equipment	5,047		3,771.5
Finance Lease, Right-of-Use Asset, Accumulated Amortization	10		9.2
Less: accumulated depreciation	1,046.6		992.1
Finance Lease, Right-of-Use Asset, after Accumulated Amortization	3.4		3.1
Property, plant and equipment, net	4,000.4		2,779.4
Finance leases	30.5		1.7
Finance Lease, Liability, Noncurrent	1.5		1.2
Finance Lease, Liability	32		$ 2.9
Operating lease expense	3.5	$ 4.8
Finance lease expense	$ 0.9	0.9
Operating lease, liability, current, extensible enumeration	Accrued expenses and other liabilities		Accrued expenses and other liabilities
Finance lease, liability, noncurrent, extensible enumeration	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
Operating lease, liability, noncurrent, extensible enumeration	Other long-term liabilities		Other long-term liabilities
Loss on long-lived assets, net	$ 3.8	$ 1.4
Reclassification to Finance Lease Liability	28.7
Crude Oil Railcars
Lessee, Lease, Description [Line Items]
Assets Held-for-sale, Not Part of Disposal Group, Current	24.7
Loss on long-lived assets, net	$ 4

Partners' Capital (Schedule of

Partners' Capital (Schedule of Partners' Capital Account, Distributions) (Details) - USD ($) $ / shares in Units, $ in Millions	Feb. 14, 2022	Feb. 07, 2022	Feb. 12, 2021	Feb. 05, 2021
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Date of Record		Feb. 7, 2022		Feb. 5, 2021
Distribution Made to Limited Partner, Distribution Date	Feb. 14, 2022		Feb. 12, 2021
Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit	$ 0.625		$ 0.625
Distribution Made to Limited Partner, Cash Distributions Paid	$ 60.9		$ 46.4

Partners' Capital (Components o

Partners' Capital (Components of Net Income (Loss) Attributable to Non-Controlling Interests) (Details) $ in Millions	1 Months Ended
	Apr. 30, 2022USD ($)
Crestwood Niobrara LLC | Subsequent Event
Distribution Made to Limited Partner [Line Items]
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	$ (10.3)

Partners' Capital (Narrative) (

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

May 13, 2022

May 06, 2022

Apr. 14, 2022

Feb. 14, 2022

Feb. 07, 2022

Feb. 01, 2022

Feb. 12, 2021

Feb. 05, 2021

Mar. 31, 2021

Feb. 28, 2021

Mar. 31, 2022

Mar. 31, 2021

Distribution Made to Limited Partner [Line Items]

Distribution Made to Limited Partner, Distribution Date

Feb. 14, 2022

Feb. 12, 2021

Distribution Made to Limited Partner, Date of Record

Feb. 7, 2022

Feb. 5, 2021

Distributions to preferred unitholders

$ 15

$ 15

Incentive Distribution, Distribution

60.9

46.4

Distributions to non-controlling partner

10.3

9.3

Distribution Made to Limited Partner, Cash Distributions Paid

$ 60.9

$ 46.4

Cash Paid to Repurchase Common Stock

$ 268

Noncash Distribution to Parent

2.6

Common Units

Distribution Made to Limited Partner [Line Items]

Stock exchanged (in shares)

11,500,000

Subordinated Units

Distribution Made to Limited Partner [Line Items]

Stock exchanged (in shares)

400,000

Crestwood Midstream Partners LP

Distribution Made to Limited Partner [Line Items]

Incentive Distribution, Distribution

238.1

334

Distributions to non-controlling partner

10.3

9.3

Distribution Made to General Partner, Cash Distributions Paid

238.1

334

Common unit

Distribution Made to Limited Partner [Line Items]

Transaction Costs

$ 7.6

$ 7.6

Partners' Capital | Crestwood Midstream Partners LP

Distribution Made to Limited Partner [Line Items]

Non-cash contribution from partner (Note 11)

$ 1,075.1

1,075.1

Partners' Capital Account, Contributions

$ 14.9

Common Units

Distribution Made to Limited Partner [Line Items]

Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period

526,322

Oasis Midstream Public Unitholders | Oasis Midstream Partners LP

Distribution Made to Limited Partner [Line Items]

Issued shares (in shares)

12,900,000

Subsequent Event

Distribution Made to Limited Partner [Line Items]

Distribution Made to Limited Partner, Distribution Date

May 13, 2022

Distribution Made to Limited Partner, Date of Record

May 6, 2022

Distributions to preferred unitholders

$ 15

Cash Distribution | Subsequent Event

Distribution Made to Limited Partner [Line Items]

Distribution Made to Limited Partner, Distributions Declared, Per Unit

$ 0.655

Crestwood LTIP

Distribution Made to Limited Partner [Line Items]

Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount

$ 4.6

Crestwood LTIP | Performance Shares

Distribution Made to Limited Partner [Line Items]

Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period

177,025

206,017

Share-based Payment Arrangement, Noncash Expense

$ 0.2

Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period

3 years

Partners' Capital Rollforward o

Partners' Capital Rollforward of non-controlling interest (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Apr. 30, 2022	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021	Dec. 31, 2020
Increase (Decrease) in Temporary Equity [Roll Forward]
Temporary Equity, Net Income		$ 10.2	$ 10.1
Interest of non-controlling partner in subsidiary		434.5	433.5	$ 434.6	$ 432.7
Subsequent Event | Crestwood Niobrara LLC
Increase (Decrease) in Temporary Equity [Roll Forward]
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	$ (10.3)
Non-Controlling Partners
Increase (Decrease) in Temporary Equity [Roll Forward]
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders		$ (10.3)	$ (9.3)

Earnings Per Limited Partner _3

Earnings Per Limited Partner Unit (Details) - shares shares in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Preferred Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	7.1	7.1
Performance Shares
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	0.3	0.1
Subordinated Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	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, Amount	3.6	4.2

Segments (Reconciliation of Net

Segments (Reconciliation of Net Income (Loss) to EBITDA) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022USD ($)segment	Mar. 31, 2021USD ($)
Segment Reporting, Other Significant Reconciling Item [Line Items]
Number of Operating Segments | segment	3
Net income (loss)	$ 22.2	$ (38.3)
Interest and debt expense, net	36.1	36
Benefit for income taxes	0	(0.1)
Depreciation, amortization and accretion	74.8	59.2
EBITDA	133.1	62.3
Loss on modification/extinguishment of debt	0	5.5
Crestwood Midstream Partners LP
Segment Reporting, Other Significant Reconciling Item [Line Items]
Net income (loss)	20.2	(40.4)
Interest and debt expense, net	36.1	36
Benefit for income taxes	0	(0.1)
Depreciation, amortization and accretion	78.2	62.8
EBITDA	134.5	63.8
Loss on modification/extinguishment of debt	$ 0	$ 5.5

Segments (Summary Of Segment In

Segments (Summary Of Segment Information) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022USD ($)segment	Mar. 31, 2021USD ($)	Dec. 31, 2021USD ($)
Net income (loss)	$ 22.2	$ (38.3)
Number of Operating Segments | segment	3
Depreciation, amortization and accretion	$ 74.8	59.2
Segment Reporting Information, Additional Information [Abstract]
Revenues	1,583.8	1,032.7
Costs of product/services sold	1,364.4	813.8
Operations and maintenance	42.4	32.8
General and administrative	43.4	18.7
Gain (loss) on long-lived assets	(3.8)	(1.4)
Earnings (loss) from unconsolidated affiliates, net	3	(103.7)
Other income, net	0.3	0
EBITDA	133.1	62.3
Assets	6,240.1		$ 4,445.7
Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Revenues	(127.4)	(105.3)
Gathering and Processing North | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Revenues	362.6	235.1
Gathering and Processing South | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Revenues	30.7	24.6
Storage and Logistics | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Revenues	1,317.9	878.3
Crestwood Midstream Partners LP
Net income (loss)	20.2	(40.4)
Depreciation, amortization and accretion	78.2	62.8
Segment Reporting Information, Additional Information [Abstract]
Revenues	1,583.8	1,032.7
Costs of product/services sold	1,364.4	813.8
Operations and maintenance	42.4	32.8
General and administrative	41.7	17.2
Gain (loss) on long-lived assets	(3.8)	(1.4)
Earnings (loss) from unconsolidated affiliates, net	3	(103.7)
EBITDA	134.5	63.8
Assets	6,362.1		4,571.2
Crestwood Midstream Partners LP | Corporate, Non-Segment
Segment Reporting Information, Additional Information [Abstract]
Revenues	0	0
Costs of product/services sold	0	0
Operations and maintenance	0	0
General and administrative	41.7	17.2
Gain (loss) on long-lived assets	0	0
Earnings (loss) from unconsolidated affiliates, net	0	0
EBITDA	(41.7)	(17.2)
Assets	24.3		20.7
Crestwood Midstream Partners LP | Corporate and Eliminations [Member]
Segment Reporting Information, Additional Information [Abstract]
Revenues	0	0
Crestwood Midstream Partners LP | Gathering and Processing North | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Revenues	235.2	129.8
Costs of product/services sold	205.6	116.2
Operations and maintenance	23.7	15.1
General and administrative	0	0
Gain (loss) on long-lived assets	0	(0.2)
Earnings (loss) from unconsolidated affiliates, net	0	0
EBITDA	133.3	103.6
Assets	4,090.1		2,408
Crestwood Midstream Partners LP | Gathering and Processing North | Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Revenues	127.4	105.3
Crestwood Midstream Partners LP | Gathering and Processing South | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Revenues	30.7	24.6
Costs of product/services sold	(0.6)	0.3
Operations and maintenance	6.7	6.3
General and administrative	0	0
Gain (loss) on long-lived assets	0.2	(1.3)
Earnings (loss) from unconsolidated affiliates, net	2.6	(0.8)
EBITDA	27.4	15.9
Assets	1,150.4		1,017.4
Crestwood Midstream Partners LP | Gathering and Processing South | Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Revenues	0	0
Crestwood Midstream Partners LP | Storage and Logistics | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Revenues	1,317.9	878.3
Costs of product/services sold	1,159.4	697.3
Operations and maintenance	12	11.4
General and administrative	0	0
Gain (loss) on long-lived assets	(4)	0.1
Earnings (loss) from unconsolidated affiliates, net	0.4	(102.9)
EBITDA	15.5	(38.5)
Assets	1,097.3		1,125.1
Crestwood Midstream Partners LP | Storage and Logistics | Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Revenues	(127.4)	(105.3)
Crestwood Equity Partners LP
Segment Reporting Information, Additional Information [Abstract]
General and administrative	1.7	1.5
Other income, net	0.3
EBITDA	133.1	62.3
Assets	6,240.1		4,445.7
Crestwood Equity Partners LP | Corporate, Non-Segment
Segment Reporting Information, Additional Information [Abstract]
General and administrative	1.7	1.5
Other income, net	0.3
EBITDA	(43.1)	(18.7)
Assets	29.6		26.1
Crestwood Equity Partners LP | Gathering and Processing North | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
General and administrative	0	0
Other income, net	0
EBITDA	133.3	103.6
Assets	4,090.1		2,408
Crestwood Equity Partners LP | Gathering and Processing South | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
General and administrative	0	0
Other income, net	0
EBITDA	27.4	15.9
Assets	1,023.1		886.5
Crestwood Equity Partners LP | Storage and Logistics | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
General and administrative	0	0
Other income, net	0
EBITDA	15.5	$ (38.5)
Assets	$ 1,097.3		$ 1,125.1

Segments (Narrative) (Details)

Segments (Narrative) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022USD ($)segment	Mar. 31, 2021USD ($)
Segment Reporting Information [Line Items]
Interest, taxes, depreciation and amortization included in earnings from equity method investments | $	$ 4.6	$ 129.4
Number of Operating Segments | segment	3

Revenues (Narrative) (Details)

Revenues (Narrative) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Revenue Recognition [Abstract]
ASC 606 accounts receivable	$ 429.8	$ 331

Revenues (Contract Assets and L

Revenues (Contract Assets and Liabilities) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Dec. 31, 2021
Revenue Recognition [Abstract]
Contract Assets (Non-current)	$ 1.2	$ 1.3
Contract liabilities	11	10.7
Contract liabilities	202.1	$ 187.1
Contract with Customer, Liability, Revenue Recognized	$ 3.5

Revenues (Disaggregation of Rev

Revenues (Disaggregation of Revenue) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Disaggregation of Revenue [Line Items]
Revenues	$ 1,583.8	$ 1,032.7
Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	48.3	31.4
Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	15.8	20.7
Water Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	36.9	22
Natural Gas Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	15.5	7
Natural Gas Compression
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3.5	4.7
Crude Oil Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.4	0.2
NGL Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2.8	3.7
Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.5	0.8
Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.3	0.7
NGL Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5.8	4.2
Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.4	1
Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	110.8	96.2
Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	490.9	318.5
NGL Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	645.6	406
Other revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.5	0.2
Water Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.6
Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenues	(127.4)	(105.3)
Intersegment Eliminations | Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Intersegment Eliminations | Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Intersegment Eliminations | Water Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Intersegment Eliminations | Natural Gas Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Intersegment Eliminations | Natural Gas Compression
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Intersegment Eliminations | Crude Oil Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(0.1)	(0.1)
Intersegment Eliminations | NGL Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Intersegment Eliminations | Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Intersegment Eliminations | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Intersegment Eliminations | NGL Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Intersegment Eliminations | Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Intersegment Eliminations | Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(52.1)	(42.2)
Intersegment Eliminations | Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(11.2)	(22.7)
Intersegment Eliminations | NGL Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(64)	(40.3)
Intersegment Eliminations | Other revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Intersegment Eliminations | Water Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Operating Segments | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenues	362.6	235.1
Operating Segments | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenues	30.7	24.6
Operating Segments | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenues	1,317.9	878.3
Operating Segments | Natural Gas Gathering | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	25.9	13.2
Operating Segments | Natural Gas Gathering | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	22.4	18.2
Operating Segments | Natural Gas Gathering | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Crude Oil Gathering | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	14.8	20.7
Operating Segments | Crude Oil Gathering | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1	0
Operating Segments | Crude Oil Gathering | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Water Gathering | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	34.7	22
Operating Segments | Water Gathering | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2.2	0
Operating Segments | Water Gathering | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Natural Gas Processing | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	14.4	5.8
Operating Segments | Natural Gas Processing | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.1	1.2
Operating Segments | Natural Gas Processing | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Natural Gas Compression | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Natural Gas Compression | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3.5	4.7
Operating Segments | Natural Gas Compression | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Crude Oil Storage | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.5	0.1
Operating Segments | Crude Oil Storage | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Crude Oil Storage | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0.2
Operating Segments | NGL Storage | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | NGL Storage | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | NGL Storage | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2.8	3.7
Operating Segments | Crude Oil Pipeline | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Crude Oil Pipeline | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Crude Oil Pipeline | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.5	0.8
Operating Segments | Crude Oil Transportation | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.2	0.7
Operating Segments | Crude Oil Transportation | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.1	0
Operating Segments | Crude Oil Transportation | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | NGL Transportation | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | NGL Transportation | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | NGL Transportation | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5.8	4.2
Operating Segments | Crude Oil Rail Loading | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Crude Oil Rail Loading | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Crude Oil Rail Loading | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.4	1
Operating Segments | Natural Gas Product Sales | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	63.9	42.3
Operating Segments | Natural Gas Product Sales | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.3	0.5
Operating Segments | Natural Gas Product Sales | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	98.7	95.6
Operating Segments | Crude Oil Product Sales | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	128.1	90
Operating Segments | Crude Oil Product Sales | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Crude Oil Product Sales | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	374	251.2
Operating Segments | NGL Product Sales | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	76.9	40.3
Operating Segments | NGL Product Sales | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | NGL Product Sales | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	632.7	406
Operating Segments | Other revenue | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.2	0
Operating Segments | Other revenue | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0
Operating Segments | Other revenue | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.3	0.2
Operating Segments | Water Product Sales | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.6
Operating Segments | Water Product Sales | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Operating Segments | Water Product Sales | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Revenue from Contract with Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,380.6	917.3
Revenue from Contract with Customer | Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(127.4)	(105.3)
Revenue from Contract with Customer | Operating Segments | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	362.2	235.1
Revenue from Contract with Customer | Operating Segments | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	30.6	24.6
Revenue from Contract with Customer | Operating Segments | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,115.2	762.9
Product and Service, Other
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	203.2	115.4
Product and Service, Other | Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	0	0
Product and Service, Other | Operating Segments | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	0.4	0
Product and Service, Other | Operating Segments | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	0.1	0
Product and Service, Other | Operating Segments | Storage and Logistics
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	$ 202.7	$ 115.4

Revenues (Remaining Performance

Revenues (Remaining Performance Obligations) (Details) $ in Millions	Mar. 31, 2022USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 179.7
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	9 months
Revenue, Remaining Performance Obligation, Amount	$ 65.8
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 65.1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 44.4
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 2.6
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 0.5
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Revenue, Remaining Performance Obligation, Amount	$ 1.3
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 Obligation, Expected Timing of Satisfaction, Period	15 years

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Related Party Transaction [Line Items]
Purchases of property, plant and equipment	$ 26.4	$ 9.3
Costs of product/services sold at CEQP and CMLP(2)	68.5	41.1
Operations and maintenance expenses charged by CEQP and CMLP	4.8	5.7
Related Party Transaction, Due from (to) Related Party [Abstract]
Related party receivables	60.2		$ 8.2
Related party payables	16.4		$ 12
Revenues	1,583.8	1,032.7
Product
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues	1,390.5	930.6
Service
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues	95.6	97.2
Applied Consultants, Inc.
Related Party Transaction [Line Items]
Purchases of property, plant and equipment		0.3
Crestwood Permian Basin Holdings LLC
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP	1.6	4.9
Costs of product/services sold at CEQP and CMLP(2)	36.2	30.3
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues	0.5
Tres Palacios Holdings LLC
Related Party Transaction [Line Items]
Costs of product/services sold at CEQP and CMLP(2)	0.9	10.8
Affiliated Entity
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP	97.7	4.9
Costs of product/services sold at CEQP and CMLP(2)	68.5	41.1
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	7.5	5.9
Oasis Petroleum Inc.
Related Party Transaction [Line Items]
Costs of product/services sold at CEQP and CMLP(2)	31.4
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	0.9	0
Oasis Petroleum Inc. | Product
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP	59
Oasis Petroleum Inc. | Service
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP	36.6
Crestwood Equity Partners LP | Affiliated Entity
Related Party Transaction [Line Items]
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party		0.2
Crestwood Midstream Partners LP
Related Party Transaction [Line Items]
Purchases of property, plant and equipment	26.4	9.3
Costs of product/services sold at CEQP and CMLP(2)	68.5	41.1
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues	1,583.8	1,032.7
Crestwood Midstream Partners LP | Product
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues	1,390.5	930.6
Crestwood Midstream Partners LP | Service
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues	95.6	97.2
Crestwood Midstream Partners LP | Affiliated Entity
Related Party Transaction [Line Items]
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	1.1	1
Crestwood LTIP | Crestwood Midstream Partners LP
Related Party Transaction [Line Items]
Share-based Payment Arrangement, Expense	8.6	6.9
Crestwood LTIP | Crestwood Holdings
Related Party Transaction [Line Items]
Share-based Payment Arrangement, Expense		4.6
Stagecoach Gas Services LLC
Related Party Transaction [Line Items]
Operations and maintenance expenses charged by CEQP and CMLP		1.7
Tres Palacios Holdings LLC
Related Party Transaction [Line Items]
Operations and maintenance expenses charged by CEQP and CMLP	1.2	1.2
Crestwood Permian Basin Holdings LLC
Related Party Transaction [Line Items]
Operations and maintenance expenses charged by CEQP and CMLP	$ 3.6	$ 2.8