10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2022

OR

☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from               to              .

(Exact name of registrant as specified in its charter)	Commission file number	State or other jurisdiction of incorporation or organization	(I.R.S. Employer Identification No.)
Crestwood Equity Partners LP	001-34664	Delaware	43-1918951
Crestwood Midstream Partners LP	001-35377	Delaware	20-1647837

811 Main Street	Suite 3400	Houston	Texas	77002
(Address of principal executive offices)				(Zip code)

(832) 519-2200

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

	Title of each class	Trading Symbol	Name of each exchange on which registered
Crestwood Equity Partners LP	Common Units representing limited partnership interests	CEQP	New York Stock Exchange
Crestwood Equity Partners LP	Preferred Units representing limited partnership interests	CEQP-P	New York Stock Exchange
Crestwood Midstream Partners LP	None	None	None

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Crestwood Equity Partners LP	Yes	☒	No	☐
Crestwood Midstream Partners LP	Yes	☒	No	☐

(Explanatory Note: Crestwood Midstream Partners LP is currently a voluntary filer and is not subject to the filing requirements of the Securities Exchange Act of 1934. Although not subject to these filing requirements, Crestwood Midstream Partners LP has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months.)

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

Crestwood Equity Partners LP	Yes	☒	No	☐
Crestwood Midstream Partners LP	Yes	☒	No	☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Crestwood Equity Partners LP	Large accelerated filer	☒	Accelerated filer	☐	Non-accelerated filer	☐	Smaller reporting company	☐	Emerging growth company	☐
Crestwood Midstream Partners LP	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.

Crestwood Equity Partners LP	☐
Crestwood Midstream Partners LP	☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Crestwood Equity Partners LP	Yes	☐	No	☒
Crestwood Midstream Partners LP	Yes	☐	No	☒

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date (October 28, 2022).

Crestwood Equity Partners LP	104,652,379
Crestwood Midstream Partners LP	None

Crestwood Midstream Partners LP, as a wholly-owned subsidiary of a reporting company, meets the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and is therefore filing this report with the reduced disclosure format as permitted by such instruction.

CRESTWOOD EQUITY PARTNERS LP

CRESTWOOD MIDSTREAM PARTNERS LP

INDEX TO FORM 10-Q

	Page
Part I – Financial Information
Item 1. Financial Statements (Unaudited):
Crestwood Equity Partners LP
Consolidated Balance Sheets	4
Consolidated Statements of Operations	5
Consolidated Statements of Partners’ Capital	6
Consolidated Statements of Cash Flows	8
Crestwood Midstream Partners LP
Consolidated Balance Sheets	9
Consolidated Statements of Operations	10
Consolidated Statements of Partners’ Capital	11
Consolidated Statements of Cash Flows	12
Notes to Consolidated Financial Statements	13
Note 1. Organization and Business Description	13
Note 2. Basis of Presentation and Summary of Significant Accounting Policies	13
Note 3. Acquisitions and Divestitures	14
Note 4. Certain Balance Sheet Information	19
Note 5. Investments in Unconsolidated Affiliates	20
Note 6. Risk Management	21
Note 7. Fair Value Measurements	22
Note 8. Long-Term Debt	24
Note 9. Commitments and Contingencies	26
Note 10. Leases	27
Note 11. Partners’ Capital and Non-Controlling Partner	28
Note 12. Earnings Per Limited Partner Unit	30
Note 13. Segments	31
Note 14. Revenues	34
Note 15. Related Party Transactions	39
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	41
Item 3. Quantitative and Qualitative Disclosures About Market Risk	53
Item 4. Controls and Procedures	53
Part II – Other Information
Item 1. Legal Proceedings	55
Item 1A. Risk Factors	55
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	55
Item 3. Defaults Upon Senior Securities	55
Item 4. Mine Safety Disclosures	55
Item 5. Other Information	55
Item 6. Exhibits	56
Signature	58

3

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements

CRESTWOOD EQUITY PARTNERS LP

CONSOLIDATED BALANCE SHEETS

(in millions, except unit information)

	September 30, 2022		December 31, 2021
	(unaudited)
Assets
Current assets:
Cash	$	6.4	$	13.3
Accounts receivable, less allowance for doubtful accounts of $0.6 million      at both September 30, 2022 and December 31, 2021	479.8		378.0
Inventory	159.1		156.5
Assets from price risk management activities	112.7		42.1
Assets held for sale, net	205.7		—
Prepaid expenses and other current assets	9.2		14.8
Total current assets	972.9		604.7
Property, plant and equipment	5,141.4		3,771.5
Less: accumulated depreciation	752.1		992.1
Property, plant and equipment, net	4,389.3		2,779.4
Intangible assets	1,420.2		1,126.1
Less: accumulated amortization	285.1		393.2
Intangible assets, net	1,135.1		732.9
Goodwill	251.3		138.6
Operating lease right-of-use assets, net	18.6		27.4
Investments in unconsolidated affiliates	121.4		155.8
Other non-current assets	10.8		6.9
Total assets	$	6,899.4	$	4,445.7
Liabilities and capital
Current liabilities:
Accounts payable	$	386.2	$	336.5
Accrued expenses and other liabilities	204.5		147.1
Liabilities from price risk management activities	36.9		114.6
Current portion of long-term debt	—		0.2
Total current liabilities	627.6		598.4
Long-term debt, less current portion	3,570.0		2,052.1
Other long-term liabilities	325.7		258.7
Deferred income taxes	3.5		2.3
Total liabilities	4,526.8		2,911.5
Commitments and contingencies (Note 9)
Interest of non-controlling partner in subsidiary	434.4		434.6
Crestwood Equity Partners LP partners’ capital (104,651,317 and 62,991,511 common units issued and outstanding at September 30, 2022 and December 31, 2021)	1,326.2		487.6
Preferred units (71,257,445 units issued and outstanding at both September 30, 2022 and December 31, 2021)	612.0		612.0
Total partners’ capital	1,938.2		1,099.6
Total liabilities and capital	$	6,899.4	$	4,445.7

See accompanying notes.

4

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF OPERATIONS (in millions, except per unit data) (unaudited)
	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
Revenues:
Product revenues	$	1,332.8	$	1,120.8	$	3,938.3	$	2,872.1
Product revenues - related party (Note 15)	83.2		6.5		222.7		24.2
Service revenues	92.4		98.4		286.8		291.3
Service revenues - related party (Note 15)	57.6		0.6		150.0		1.0
Total revenues	1,566.0		1,226.3		4,597.8		3,188.6
Costs of product/services sold (exclusive of items shown separately below):
Product costs	1,228.6		1,060.2		3,613.4		2,595.8
Product costs - related party (Note 15)	51.3		34.8		232.9		101.3
Service costs	6.9		4.3		18.1		13.2
Total costs of products/services sold	1,286.8		1,099.3		3,864.4		2,710.3
Operating expenses and other:
Operations and maintenance	55.0		31.6		144.0		90.2
General and administrative	33.9		25.9		103.8		67.4
Depreciation, amortization and accretion	86.9		64.6		242.3		182.6
Loss on long-lived assets, net	175.9		18.5		186.9		19.6
Gain on acquisition	(75.3)		—		(75.3)		—
	276.4		140.6		601.7		359.8
Operating income (loss)	2.8		(13.6)		131.7		118.5
Earnings (loss) from unconsolidated affiliates, net	3.2		4.9		12.2		(125.9)
Interest and debt expense, net	(47.6)		(30.9)		(123.8)		(102.0)
Loss on modification/extinguishment of debt	—		—		—		(6.7)
Other income, net	—		0.1		0.2		0.2
Income (loss) before income taxes	(41.6)		(39.5)		20.3		(115.9)
Provision for income taxes	(1.4)		(0.1)		(1.7)		(0.1)
Net income (loss)	(43.0)		(39.6)		18.6		(116.0)
Net income attributable to non-controlling partner	10.3		10.3		30.8		30.7
Net loss attributable to Crestwood Equity Partners LP	(53.3)		(49.9)		(12.2)		(146.7)
Net income attributable to preferred units	15.0		15.0		45.0		45.0
Net loss attributable to partners	$	(68.3)	$	(64.9)	$	(57.2)	$	(191.7)
Net loss per limited partner unit: (Note 12)
Basic and Diluted	$	(0.64)	$	(1.03)	$	(0.59)	$	(2.88)
Weighted-average limited partners’ units outstanding:
Basic and Diluted	107.1		62.9		97.1		66.6

See accompanying notes.

5

CRESTWOOD EQUITY PARTNERS LP

CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL

(in millions)

(unaudited)

	Preferred			Common
	Units	Capital		Units	Capital		Total Partners’ Capital
Balance at December 31, 2021	71.3	$	612.0	63.0	$	487.6	$	1,099.6
Distributions to partners	—	(15.0)		—	(60.9)		(75.9)
Issuance of common units (Note 3)	—	—		33.8	930.0		930.0
Unit-based compensation charges	—	—		1.6	13.0		13.0
Taxes paid for unit-based compensation vesting	—	—		(0.5)	(14.9)		(14.9)
Other	—	—		0.1	2.2		2.2
Net income (loss)	—	15.0		—	(3.0)		12.0
Balance at March 31, 2022	71.3	612.0		98.0	1,354.0		1,966.0
Distributions to partners	—	(15.0)		—	(64.2)		(79.2)
Unit-based compensation charges	—	—		—	8.6		8.6
Taxes paid for unit-based compensation vesting	—	—		—	(0.7)		(0.7)
Other	—	—		—	(0.4)		(0.4)
Net income	—	15.0		—	14.1		29.1
Balance at June 30, 2022	71.3	612.0		98.0	1,311.4		1,923.4
Distributions to partners	—	(15.0)		—	(71.6)		(86.6)
Issuance of common units (Note 3)	—	—		11.3	270.8		270.8
Purchase of common units (Note 11)	—	—		—	(123.7)		(123.7)
Retirement of common units (Note 11)	—	—		(4.6)	—		—
Unit-based compensation charges	—	—		—	8.0		8.0
Taxes paid for unit-based compensation vesting	—	—		—	(0.2)		(0.2)
Other	—	—		—	(0.2)		(0.2)
Net income (loss)	—	15.0		—	(68.3)		(53.3)
Balance at September 30, 2022	71.3	$	612.0	104.7	$	1,326.2	$	1,938.2

6

CRESTWOOD EQUITY PARTNERS LP

CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL (continued)

(in millions)

(unaudited)

	Preferred			Partners
	Units	Capital		Common Units	Subordinated Units	Capital		Total Partners’ Capital
Balance at December 31, 2020	71.3	$	612.0	73.6	0.4	$	1,043.4	$	1,655.4
Crestwood Holdings Transactions (Note 11)	—	—		—	—	(273.2)		(273.2)
Retirement of units (Note 11)	—	—		(11.5)	(0.4)	—		—
Distributions to partners	—	(15.0)		—	—	(46.4)		(61.4)
Unit-based compensation charges	—	—		1.1	—	3.7		3.7
Taxes paid for unit-based compensation vesting	—	—		(0.4)	—	(8.1)		(8.1)
Other	—	—		—	—	(0.4)		(0.4)
Net income (loss)	—	15.0		—	—	(63.4)		(48.4)
Balance at March 31, 2021	71.3	612.0		62.8	—	655.6		1,267.6
Distributions to partners	—	(15.0)		—	—	(39.3)		(54.3)
Unit-based compensation charges	—	—		—	—	7.6		7.6
Taxes paid for unit-based compensation vesting	—	—		—	—	(0.1)		(0.1)
Other	—	—		—	—	(0.3)		(0.3)
Net income (loss)	—	15.0		—	—	(63.4)		(48.4)
Balance at June 30, 2021	71.3	612.0		62.8	—	560.1		1,172.1
Distributions to partners	—	(15.0)		—	—	(39.3)		(54.3)
Unit-based compensation charges	—	—		0.1	—	9.6		9.6
Taxes paid for unit-based compensation vesting	—	—		—	—	(0.1)		(0.1)
Other	—	—		—	—	(1.1)		(1.1)
Net income (loss)	—	15.0		—	—	(64.9)		(49.9)
Balance at September 30, 2021	71.3	$	612.0	62.9	—	$	464.3	$	1,076.3

See accompanying notes.

7

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF CASH FLOWS (in millions) (unaudited)
	Nine Months Ended
	September 30,
	2022		2021
Operating activities
Net income (loss)	$	18.6	$	(116.0)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	242.3		182.6
Amortization of debt-related deferred costs and fair value adjustment	1.7		5.1
Unit-based compensation charges	26.8		22.8
Loss on long-lived assets, net	186.9		19.6
Gain on acquisition	(75.3)		—
Loss on modification/extinguishment of debt	—		6.7
(Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received	(0.9)		137.5
Deferred income taxes	1.1		(0.4)
Other	—		0.2
Changes in operating assets and liabilities	(123.9)		114.8
Net cash provided by operating activities	277.3		372.9
Investing activities
Acquisitions, net of cash acquired (Note 3)	(604.3)		—
Purchases of property, plant and equipment	(147.3)		(55.8)
Investments in unconsolidated affiliates	(90.2)		(10.2)
Capital distributions from unconsolidated affiliates	9.4		648.4
Net proceeds from sale of assets	315.2		0.5
Net cash provided by (used in) investing activities	(517.2)		582.9
Financing activities
Proceeds from the issuance of long-term debt	3,072.0		2,236.4
Payments on long-term debt	(2,393.1)		(2,695.9)
Payments on finance leases	(31.3)		(2.1)
Payments for deferred financing costs	(1.8)		(11.1)
Net proceeds from issuance of non-controlling interest	—		1.0
Payments for Crestwood Holdings Transactions	—		(275.6)
Purchase of common units	(123.7)		—
Distributions to partners	(196.7)		(125.0)
Distributions to non-controlling partner	(31.0)		(29.9)
Distributions to preferred unitholders	(45.0)		(45.0)
Taxes paid for unit-based compensation vesting	(15.8)		(8.3)
Other	(0.6)		—
Net cash provided by (used in) financing activities	233.0		(955.5)
Net change in cash	(6.9)		0.3
Cash at beginning of period	13.3		14.0
Cash at end of period	$	6.4	$	14.3
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$	19.9	$	(9.2)

See accompanying notes.

8

CRESTWOOD MIDSTREAM PARTNERS LP

CONSOLIDATED BALANCE SHEETS

(in millions)

	September 30, 2022		December 31, 2021
	(unaudited)
Assets
Current assets:
Cash	$	5.8	$	12.9
Accounts receivable, less allowance for doubtful accounts of $0.6 million      at both September 30, 2022 and December 31, 2021	479.8		378.0
Inventory	159.1		156.5
Assets from price risk management activities	112.7		42.1
Assets held for sale, net	205.7		—
Prepaid expenses and other current assets	9.2		14.4
Total current assets	972.3		603.9
Property, plant and equipment	5,138.2		4,100.8
Less: accumulated depreciation	752.0		1,193.0
Property, plant and equipment, net	4,386.2		2,907.8
Intangible assets	1,420.2		1,126.1
Less: accumulated amortization	285.1		393.2
Intangible assets, net	1,135.1		732.9
Goodwill	251.3		138.6
Operating lease right-of-use assets, net	18.6		27.4
Investments in unconsolidated affiliates	121.4		155.8
Other non-current assets	8.7		4.8
Total assets	$	6,893.6	$	4,571.2
Liabilities and capital
Current liabilities:
Accounts payable	$	386.1	$	336.4
Accrued expenses and other liabilities	203.3		146.1
Liabilities from price risk management activities	36.9		114.6
Current portion of long-term debt	—		0.2
Total current liabilities	626.3		597.3
Long-term debt, less current portion	3,570.0		2,052.1
Other long-term liabilities	323.6		254.1
Deferred income taxes	2.2		0.8
Total liabilities	4,522.1		2,904.3
Commitments and contingencies (Note 9)
Interest of non-controlling partner in subsidiary	434.4		434.6
Partners’ capital	1,937.1		1,232.3
Total liabilities and capital	$	6,893.6	$	4,571.2

See accompanying notes.

9

CRESTWOOD MIDSTREAM PARTNERS LP

CONSOLIDATED STATEMENTS OF OPERATIONS

(in millions)

(unaudited)

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
Revenues:
Product revenues	$	1,332.8	$	1,120.8	$	3,938.3	$	2,872.1
Product revenues - related party (Note 15)	83.2		6.5		222.7		24.2
Service revenues	92.4		98.4		286.8		291.3
Service revenues - related party (Note 15)	57.6		0.6		150.0		1.0
Total revenues	1,566.0		1,226.3		4,597.8		3,188.6
Costs of product/services sold (exclusive of items shown separately below):
Product costs	1,228.6		1,060.2		3,613.4		2,595.8
Product costs - related party (Note 15)	51.3		34.8		232.9		101.3
Service costs	6.9		4.3		18.1		13.2
Total costs of product/services sold	1,286.8		1,099.3		3,864.4		2,710.3
Operating expenses and other:
Operations and maintenance	55.0		31.6		144.0		90.2
General and administrative	32.3		24.4		99.0		61.3
Depreciation, amortization and accretion	86.8		68.2		248.0		193.2
Loss on long-lived assets, net	247.6		18.5		311.9		19.6
Gain on acquisition	(75.3)		—		(75.3)		—
	346.4		142.7		727.6		364.3
Operating income (loss)	(67.2)		(15.7)		5.8		114.0
Earnings (loss) from unconsolidated affiliates, net	3.2		4.9		12.2		(125.9)
Interest and debt expense, net	(47.6)		(30.9)		(123.8)		(102.0)
Loss on modification/extinguishment of debt	—		—		—		(6.7)
Loss before income taxes	(111.6)		(41.7)		(105.8)		(120.6)
Provision for income taxes	(1.4)		(0.1)		(1.6)		(0.1)
Net loss	(113.0)		(41.8)		(107.4)		(120.7)
Net income attributable to non-controlling partner	10.3		10.3		30.8		30.7
Net loss attributable to Crestwood Midstream Partners LP	$	(123.3)	$	(52.1)	$	(138.2)	$	(151.4)

See accompanying notes.

10

CRESTWOOD MIDSTREAM PARTNERS LP

CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL

(in millions)

(unaudited)

	Total Partners’ Capital
Balance at December 31, 2021	$	1,232.3
Non-cash contribution from partner (Note 11)	1,075.1
Cash contribution from partner (Note 11)	14.9
Distributions to partners	(238.1)
Unit-based compensation charges	13.0
Taxes paid for unit-based compensation vesting	(14.9)
Other	0.1
Net income	10.0
Balance at March 31, 2022	2,092.4
Distributions to partners	(81.6)
Unit-based compensation charges	8.6
Taxes paid for unit-based compensation vesting	(0.7)
Net loss	(24.9)
Balance at June 30, 2022	1,993.8
Non-cash contribution from partner (Note 11)	127.3
Cash contribution from partner (Note 11)	149.4
Distributions to partners	(217.9)
Unit-based compensation charges	8.0
Taxes paid for unit-based compensation vesting	(0.2)
Net loss	(123.3)
Balance at September 30, 2022	$	1,937.1

	Total Partners’ Capital
Balance at December 31, 2020	$	1,805.1
Distributions to partners	(334.0)
Unit-based compensation charges	2.3
Taxes paid for unit-based compensation vesting	(8.1)
Other	(0.1)
Net loss	(50.5)
Balance at March 31, 2021	1,414.7
Distributions to partners	(61.4)
Unit-based compensation charges	7.6
Taxes paid for unit-based compensation vesting	(0.1)
Net loss	(48.8)
Balance at June 30, 2021	1,312.0
Distributions to partners	(55.9)
Unit-based compensation charges	9.6
Taxes paid for unit-based compensation vesting	(0.1)
Net loss	(52.1)
Balance at September 30, 2021	$	1,213.5

See accompanying notes.

11

CRESTWOOD MIDSTREAM PARTNERS LP

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)

(unaudited)

	Nine Months Ended
	September 30,
	2022		2021
Operating activities
Net loss	$	(107.4)	$	(120.7)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, amortization and accretion	248.0		193.2
Amortization of debt-related deferred costs and fair value adjustment	1.7		5.1
Unit-based compensation charges	26.8		22.8
Loss on long-lived assets, net	311.9		19.6
Gain on acquisition	(75.3)		—
Loss on modification/extinguishment of debt	—		6.7
(Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received	(0.9)		137.5
Deferred income taxes	1.2		—
Other	—		0.2
Changes in operating assets and liabilities	(123.9)		114.1
Net cash provided by operating activities	282.1		378.5
Investing activities
Acquisition, net of cash acquired (Note 3)	(602.7)		—
Purchases of property, plant and equipment	(146.6)		(55.8)
Investments in unconsolidated affiliates	(90.2)		(10.2)
Capital distributions from unconsolidated affiliates	9.4		648.4
Net proceeds from sale of assets	315.2		0.5
Net cash provided by (used in) investing activities	(514.9)		582.9
Financing activities
Proceeds from the issuance of long-term debt	3,072.0		2,236.4
Payments on long-term debt	(2,393.1)		(2,695.9)
Payments on finance leases	(31.3)		(2.1)
Payments for deferred financing costs	(1.8)		(11.1)
Net proceeds from issuance of non-controlling interest	—		1.0
Contributions from partner	164.3		—
Distributions to partners	(537.6)		(451.3)
Distributions to non-controlling partner	(31.0)		(29.9)
Taxes paid for unit-based compensation vesting	(15.8)		(8.3)
Net cash provided by (used in) financing activities	225.7		(961.2)
Net change in cash	(7.1)		0.2
Cash at beginning of period	12.9		13.7
Cash at end of period	$	5.8	$	13.9
Supplemental schedule of non-cash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$	19.9	$	(9.2)

See accompanying notes.

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CRESTWOOD EQUITY PARTNERS LP

CRESTWOOD MIDSTREAM PARTNERS LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 1 – 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 September 30, 2022 and for the three and nine months ended September 30, 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, as the context requires.

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.

Note 2 – 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.

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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.

Note 3 – Acquisitions and Divestitures

Acquisitions

During the nine months ended September 30, 2022, we completed several acquisitions which are further described below. We accounted for each of these acquisitions as business combinations using the acquisition method of accounting. In addition, the purchase accounting for each of these acquisitions reflects the adoption of Accounting Standards Update (ASU) 2021-08, Business Combinations (Topic 805) during the nine months ended September 30, 2022.

Oasis Merger

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 Oasis 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.

The fair value of the assets acquired and liabilities assumed were determined 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%. Certain 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.

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The following table summarizes the final valuation of the assets acquired and liabilities assumed at the acquisition date (in millions):

Cash	$	14.9
Other current assets	63.2
Property, plant and equipment	1,264.4
Intangible assets	464.0
Total assets acquired	1,806.5
Current liabilities	48.2
Long-term debt(1)	698.7
Other long-term liabilities(2)	25.8
Total liabilities assumed	772.7
Net assets acquired excluding goodwill	1,033.8
Goodwill	56.2
Net assets acquired	$	1,090.0

(1)    Consists of approximately $218 million outstanding borrowings under the Oasis Midstream credit facility, which was immediately repaid upon the closing of the Oasis 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 Oasis Merger, see Note 8.

(2)    Consists primarily of liabilities for asset retirement obligations of approximately $16.1 million.

The identifiable intangible assets primarily consist of customer relationships 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. We reflected approximately $48.8 million of goodwill in our gathering and processing north segment and approximately $7.4 million in our gathering and processing south segment.

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 nine months ended September 30, 2022, we recognized approximately $20.1 million of transaction costs related to the Oasis Merger, which are included in general and administrative expenses in our consolidated statements of operations. During the three and nine months ended September 30, 2022, we recognized approximately $110.8 million and $275.1 million of revenues and $37.7 million and $94.0 million of net income related to Oasis Midstream’s operations.

Sendero Acquisition

On July 11, 2022, we acquired Sendero Midstream Partners, LP (Sendero), a privately-held midstream company, for cash consideration of approximately $631.2 million (Sendero Acquisition). Sendero’s assets are located in Eddy County, New Mexico and its operations include natural gas gathering, compression and processing services.

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. 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 13%. The preliminary fair values of property, plant and equipment, intangible assets and liabilities and goodwill 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 the Sendero Acquisition in 2022.

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The following table summarizes the preliminary fair values of the assets acquired and liabilities assumed at the acquisition date (in millions):

Cash	$	28.5
Other current assets	77.9
Property, plant and equipment	440.2
Intangible assets	138.9
Other non-current assets	0.2
Total assets acquired	685.7
Current liabilities	64.1
Long-term liabilities(1)	17.8
Total liabilities assumed	81.9
Net assets acquired excluding goodwill	603.8
Goodwill	27.4
Total purchase price	$	631.2

(1)    Includes intangible liabilities of approximately $14.0 million which are further described below.

The identifiable intangible assets primarily consist of customer relationships with a weighted-average remaining life of 20 years and the identifiable intangible liabilities primarily consist of revenue contracts with a remaining life of eight years. The goodwill recognized relates primarily to the anticipated operating synergies between the assets acquired and our existing operations.

The financial results of Sendero are included in our gathering and processing south segment from the date of acquisition. During the three and nine months ended September 30, 2022, we recognized approximately $8.4 million and $9.3 million of transaction costs related to the Sendero Acquisition, which are included in general and administrative expenses in our consolidated statements of operations. During both the three and nine months ended September 30, 2022, we recognized approximately $159.0 million of revenues and $18.1 million of net income related to Sendero’s operations.

CPJV Acquisition

On July 11, 2022, we acquired First Reserve Management, L.P.’s (First Reserve) 50% equity interest in Crestwood Permian Basin Holdings LLC (Crestwood Permian) in exchange for approximately $5.9 million in cash and approximately 11.3 million newly issued CEQP common units (CPJV Acquisition). Prior to the CPJV Acquisition, we owned a 50% equity interest in Crestwood Permian, which we accounted for under the equity method of accounting. As a result of this transaction, we control and own 100% of the equity interests in Crestwood Permian.

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. 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 15%. The preliminary fair values of property, plant and equipment, intangible assets and liabilities, goodwill and an investment in an unconsolidated affiliate 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 the CPJV Acquisition in 2022.

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The following table summarizes the preliminary fair values of the assets acquired and liabilities assumed at the acquisition date (in millions):

Cash	$	149.4
Other current assets	83.3
Property, plant and equipment	453.4
Intangible assets	16.5
Investment in unconsolidated affiliate	78.6
Goodwill	29.1
Other non-current assets	4.9
Total assets acquired	815.2
Current liabilities	80.4
Long-term debt	140.2
Other long-term liabilities(1)	47.9
Total liabilities assumed	268.5
Estimated fair value of 100% of interest in Crestwood Permian	546.7
Less:
Elimination of equity interest in Crestwood Permian	194.7
Gain on acquisition of Crestwood Permian	75.3
Total purchase price	$	276.7

(1)    Includes intangible liabilities of approximately $38.9 million which are further described below.

The identifiable intangible assets primarily consist of customer relationships with a weighted-average remaining life of 20 years and the identifiable intangible liabilities primarily consist of revenue contracts with a remaining life of 10 years. The goodwill recognized relates primarily to the anticipated operating synergies between the assets acquired and our existing operations. As shown in the table above, the fair value of the assets acquired and liabilities assumed in the CPJV Acquisition exceeded the sum of the cash consideration paid, the fair value of the common units issued and the historical book value of our 50% equity interest in Crestwood Permian (which was remeasured at fair value and derecognized) and, as a result, we recognized a gain of approximately $75.3 million, which is included in gain on acquisition in our consolidated statements of operations.

The consolidated financial results of Crestwood Permian are included in our gathering and processing south segment from the date of acquisition. During the three and nine months ended September 30, 2022, we recognized approximately $0.1 million and $0.3 million of transaction costs related to the CPJV Acquisition, which are included in general and administrative expenses in our consolidated statements of operations. During both the three and nine months ended September 30, 2022, we recognized approximately $157.0 million of revenues and $8.4 million of net income related to Crestwood Permian’s operations.

The tables below present selected unaudited pro forma information as if the acquisitions described above 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 acquisitions had been completed as of the date indicated. The pro forma 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 and liabilities 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.

Our consolidated statements of operations for the three and nine months ended September 30, 2022 reflect the results of the Sendero and Crestwood Permian for the period from July 11, 2022 to September 30, 2022. The historical results for Sendero and Crestwood Permian for the period from July 1, 2022 to July 10, 2022 were not material and as a result, the tables below do not reflect selected unaudited pro forma information for the three months ended September 30, 2022.

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Crestwood Equity

	Three Months Ended September 30,		Nine Months Ended September 30,
	2021		2022		2021
Revenues	$	1,398.3	$	4,832.0	$	3,626.1
Net income (loss)	$	(23.6)	$	45.1	$	(65.1)
Net loss per limited partner unit:
Basic and Diluted	$	(0.45)	$	(0.28)	$	(1.26)

Crestwood Midstream

	Three Months Ended September 30,		Nine Months Ended September 30,
	2021		2022		2021
Revenues	$	1,398.3	$	4,832.0	$	3,626.1
Net loss	$	(25.8)	$	(156.2)	$	(69.8)

Divestitures

Barnett

On July 1, 2022, we sold our assets in the Barnett Shale to EnLink Midstream, LLC (EnLink) for approximately $290 million, including working capital adjustments. During the nine months ended September 30, 2022, Crestwood Midstream recorded a loss on the sale of approximately $53 million, which is included in loss on long-lived assets, net on its consolidated statement of operations. Crestwood Equity’s historical carrying value of the property, plant and equipment related to the Barnett Shale assets was less than the sales proceeds due to historical impairments previously recorded on the property, plant and equipment by Crestwood Equity and as a result, during the three months ended September 30, 2022, Crestwood Equity recorded a gain on the sale of approximately $72 million, which is included in gain (loss) on long-lived assets, net on its consolidated statement of operations. The sale of the Barnett assets resulted in a decrease of approximately $346.9 million and $221.9 million of property, plant and equipment, net at CMLP and CEQP, respectively, and a decrease of approximately $18.9 million in asset retirement obligations at both CMLP and CEQP. For a further description of our assets in the Barnett Shale, which were previously included in our gathering and processing south segment, see our 2021 Annual Report on Form 10-K.

Marcellus

On October 25, 2022, we sold our assets in the Marcellus Shale for approximately $206 million. As a result of the sale, we reflected these assets as current assets held for sale, net, on our consolidated balance sheets at September 30, 2022, and recorded a loss on long-lived assets of approximately $248.2 million during the three months ended September 30, 2022 for the difference between the historical carrying value of the net assets and liabilities to be sold and the proceeds received from the sale. The current assets held for sale, net, were recorded at fair value based on the sales proceeds, which is a Level 3 fair value measurement, and consist primarily of property, plant and equipment and intangible assets.

During the three months ended September 30, 2021, we recorded a loss on long-lived assets of approximately $19 million related to the abandonment and dismantlement of certain of our Marcellus West Union compressor station assets, which were located in West Virginia and provided compression and dehydration services to our customers. For a further description of our assets in the Marcellus Shale, which are included in our gathering and processing south segment, see our 2021 Annual Report on Form 10-K.

Other

During the nine months ended September 30, 2022, we recorded a loss on long-lived assets of approximately $7.0 million related to the anticipated sale of parts inventory related to our legacy Granite Wash operations.

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Note 4 – Certain Balance Sheet Information

Accrued Expenses and Other Liabilities

Accrued expenses and other liabilities consisted of the following (in millions):

	September 30,		December 31,
	2022		2021
CMLP
Accrued expenses	$	71.9	$	66.3
Accrued property taxes	8.5		4.4
Income tax payable	0.7		0.4
Interest payable	56.6		30.6
Accrued additions to property, plant and equipment	42.6		17.4
Operating leases	8.2		13.2
Finance leases	2.2		1.7
Contract liabilities	12.2		10.7
Asset retirement obligations	0.4		1.4
Total CMLP accrued expenses and other liabilities	$	203.3	$	146.1
CEQP
Accrued expenses	1.1		0.9
Income tax payable	0.1		0.1
Total CEQP accrued expenses and other liabilities	$	204.5	$	147.1

Other Long-Term Liabilities

Other long-term liabilities consisted of the following (in millions):

	September 30,		December 31,
	2022		2021
CMLP
Contract liabilities	$	209.1	$	187.1
Intangible liabilities	51.7		—
Asset retirement obligations	33.9		34.8
Operating leases	14.5		19.4
Other	14.4		12.8
Total CMLP other long-term liabilities	$	323.6	$	254.1
CEQP
Other	2.1		4.6
Total CEQP other long-term liabilities	$	325.7	$	258.7

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Note 5 - 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 Unconsolidated Affiliates				Earnings (Loss) from Unconsolidated Affiliates
					Three Months Ended				Nine Months Ended
	September 30,		December 31,		September 30,				September 30,
	2022		2021		2022		2021		2022		2021
Crestwood Permian Basin Holdings LLC(1)	$	—	$	116.1	$	1.3	$	4.2	$	8.7	$	4.4
Crestwood Permian Basin LLC(2)	77.1		—		0.7		—		0.7		—
Tres Palacios Holdings LLC(3)	41.2		36.2		1.3		(0.1)		3.2		9.1
Powder River Basin Industrial Complex, LLC(4)	3.1		3.5		(0.1)		(0.1)		(0.4)		—
Stagecoach Gas Services LLC(5)	—		—		—		0.9		—		(139.4)
Total	$	121.4	$	155.8	$	3.2	$	4.9	$	12.2	$	(125.9)

(1)On July 11, 2022, we acquired the remaining 50% equity interest in Crestwood Permian and as a result, we control and own 100% of the equity interests in Crestwood Permian. As a result of this transaction, we eliminated our historical equity investment in Crestwood Permian of approximately $194.7 million as of July 11, 2022 and began consolidating Crestwood Permian’s operations. Our Crestwood Permian investment was previously included in our gathering and processing south segment. See Note 3 for a further discussion of this acquisition.

(2)As described above, on July 11, 2022, we acquired the remaining 50% equity interest in Crestwood Permian, which owns a 50% equity interest in Crestwood Permian Basin LLC (Crestwood Permian Basin). Shell Midstream Partners L.P., a subsidiary of Royal Dutch Shell plc, owns the remaining 50% equity interest in Crestwood Permian Basin. Crestwood Permian Basin owns the Nautilus natural gas gathering system and related assets, which are further described in our 2021 Annual Report on Form 10-K. As of September 30, 2022, our equity in the underlying net assets of Crestwood Permian Basin was less than our carrying value of our investment balance by approximately $2.3 million. During the three and nine months ended September 30, 2022, we recorded amortization of less than $0.1 million related to this basis difference, which is reflected as a decrease in our earnings from unconsolidated affiliates in our consolidated statements of operations. Our Crestwood Permian Basin investment is included in our gathering and processing south segment.

(3)As of September 30, 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 $20.6 million. During both the three and nine months ended September 30, 2022 and 2021, we recorded amortization of approximately $0.3 million and $0.9 million, respectively, 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.

(4)As of September 30, 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.

(5)In 2021, we and Con Edison Gas Pipeline and Storage Northeast, LLC each sold our 50% equity interest in our Stagecoach Gas Services LLC (Stagecoach Gas) equity investment to a subsidiary of Kinder Morgan, Inc. During the nine months ended September 30, 2021, we recorded a $155.4 million reduction in our equity earnings from unconsolidated affiliates related to losses recorded by us and our Stagecoach Gas equity investment associated with the sale, which also eliminated our $51.3 million historical basis difference between our investment balance and the equity in the underlying net assets of Stagecoach Gas. In addition, our earnings from unconsolidated affiliates during the nine months ended September 30, 2021, were also reduced by our proportionate share of transaction costs of approximately $3.0 million related to the sale, which were paid by us in July 2021 on behalf of Stagecoach Gas. 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
	Nine Months Ended				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
Crestwood Permian	$	13.6	$	8.9	$	83.5	$	3.3
Crestwood Permian Basin	2.2		—		—		—
Tres Holdings	4.9		13.1		6.7		6.9
PRBIC	—		0.1		—		—
Stagecoach Gas	—		640.9		—		—
Total	$	20.7	$	663.0	$	90.2	$	10.2

(1)    In October 2022, we received a cash distribution from Tres Holdings of approximately $3.9 million. In addition, in October 2022, we made cash contributions of approximately $0.4 million and $0.3 million to Tres Holdings and PRBIC, respectively. In July 2021, Stagecoach Gas closed on the sale of certain of its wholly-owned subsidiaries to a subsidiary of Kinder Morgan as described above and distributed to us approximately $613.9 million as our proportionate share of the gross proceeds received from the sale.

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Note 6 – Risk Management

We are exposed to certain market risks related to our ongoing business operations. These risks include exposure to changing commodity prices. We utilize derivative instruments to manage our exposure to fluctuations in commodity prices, which is discussed below. Additional information related to our derivatives is discussed in Note 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				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
Product revenues	$	84.7	$	129.4	$	395.7	$	296.9
Gain (loss) reflected in product costs	$	45.0	$	(53.4)	$	(6.3)	$	(94.8)

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:

	September 30, 2022		December 31, 2021
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, ethane, butane, heating oil and crude oil (MMBbls)	66.1	69.8	71.6	75.8
Natural gas (Bcf)	38.0	43.2	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, 88% 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

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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):

	September 30, 2022		December 31, 2021
Aggregate fair value liability of derivative instruments with credit-risk-related contingent features(1)	$	15.6	$	57.9
Broker-related net derivative asset (liability) position	$	(24.0)	$	104.8
Broker-related cash collateral posted (received)	$	57.4	$	(76.8)
Cash collateral received, net	$	29.7	$	11.4

(1)At September 30, 2022 and December 31, 2021, we posted $7.2 million and $1.5 million of collateral associated with these derivatives.

Note 7 – 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 September 30, 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.

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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 September 30, 2022 and December 31, 2021 (in millions):

	September 30, 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	$	36.7	$	656.3	$	—	$	693.0	$	(584.5)	$	4.2	$	112.7
Other investments(2)	2.4		—		—		2.4		—		—		2.4
Total assets at fair value	$	39.1	$	656.3	$	—	$	695.4	$	(584.5)	$	4.2	$	115.1
Liabilities
Liabilities from price risk management	$	49.7	$	595.2	$	—	$	644.9	$	(584.5)	$	(23.5)	$	36.9
Total liabilities at fair value	$	49.7	$	595.2	$	—	$	644.9	$	(584.5)	$	(23.5)	$	36.9
	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 September 30, 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 Facilities

The fair value of the amounts outstanding under our credit facilities approximates their respective carrying amounts as of September 30, 2022 and December 31, 2021, due primarily to the variable nature of the interest rates of the instruments, which is considered a Level 2 fair value measurement. See Note 8 for a further discussion of our credit facilities.

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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):

	September 30, 2022				December 31, 2021
	Carrying  Amount		Fair Value		Carrying  Amount		Fair Value
2025 Senior Notes	$	497.3	$	473.5	$	496.5	$	511.9
2027 Senior Notes	$	595.1	$	545.6	$	594.2	$	615.0
February 2029 Senior Notes	$	691.8	$	627.2	$	690.8	$	727.3
April 2029 Senior Notes(1)	$	477.8	$	433.1	$	—	$	—

(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 is further described in Note 8.

Note 8 – Long-Term Debt

Long-term debt consisted of the following (in millions):

	September 30, 2022		December 31, 2021
CMLP Credit Facility	$	1,102.6	$	282.0
CPBH Credit Facility	216.7		—
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	27.8		—
Other	—		0.2
Less: deferred financing costs, net	27.1		29.9
Total debt	3,570.0		2,052.3
Less: current portion	—		0.2
Total long-term debt, less current portion	$	3,570.0	$	2,052.1

Credit Facilities

CMLP 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. In addition, we borrowed approximately $631.2 million under the CMLP Credit Facility to fund the Sendero Acquisition. In October 2022, we amended the CMLP Credit Facility to increase the capacity of the facility from $1.5 billion to $1.75 billion under the terms of the credit agreement.

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 September 30, 2022, the net debt to consolidated EBITDA ratio was approximately 3.93 to 1.0, the consolidated EBITDA to consolidated interest expense ratio was approximately 5.11 to 1.0, and the senior secured leverage ratio was 1.29 to 1.0.

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At September 30, 2022, Crestwood Midstream had $382.6 million of available capacity under its credit facility considering the most restrictive debt covenants in its credit agreement. At September 30, 2022 and December 31, 2021, Crestwood Midstream’s outstanding standby letters of credit were $14.8 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 4.70% and 7.25% at September 30, 2022 and 1.90% and 4.00% at December 31, 2021. The weighted-average interest rate on outstanding borrowings as of September 30, 2022 and December 31, 2021 was 4.97% and 1.91%.

CPBH Credit Facility. In conjunction with the CPJV Acquisition in July 2022, we assumed a credit agreement entered into by CPB Subsidiary Holdings LLC (CPB Holdings), a wholly-owned subsidiary of Crestwood Permian. The credit agreement allows for revolving loans, letters of credit and swing line loans of up to $230 million (the CPBH Credit Facility). The CPBH Credit Facility has an accordion feature that allows CPB Holdings to increase the available borrowings by up to an additional $85 million, subject to certain conditions. The CPBH Credit Facility matures in October 2025 and is secured by substantially all of the assets of Crestwood Permian.

Borrowings under the CPBH Credit Facility bear interest at either:

•the Alternate Base Rate, which is defined as the highest of (i) the federal funds rate plus 0.50%; (ii) Wells Fargo Bank’s prime rate; or (iii) the Adjusted Term SOFR (as defined in the credit agreement) for a one-month tenor plus 1% per annum; plus a margin varying from 1.50% to 2.50% depending on our most recent consolidated total leverage ratio; or

•the Adjusted Term SOFR plus a margin varying from 2.50% to 3.50% depending on our most recent consolidated total leverage ratio.

The unused portion of the CPBH Credit Facility is subject to a commitment fee ranging from 0.375% to 0.50% according to Crestwood Permian’s most recent consolidated total leverage ratio. Interest on the Alternate Base Rate loans is payable quarterly, or if the Adjusted Term SOFR applies, interest is payable at certain intervals selected by us.

At September 30, 2022, we had $13.3 million of available capacity under the CPBH Credit Facility considering the most restrictive covenants in the credit agreement. The interest rates on borrowings under the CPBH Credit Facility were between 5.20% and 7.75% at September 30, 2022. The weighted average interest rate on outstanding borrowings as of September 30, 2022 was 5.92%.

The CPBH Credit Facility contains various covenants and restrictive provisions that limit Crestwood Permian’s ability to, among other things, (i) incur additional debt; (ii) make distributions on or redeem or repurchase units; (iii) make certain investments and acquisitions; (iv) incur or permit certain liens to exist; (v) merge, consolidate or amalgamate with another company; and (vi) transfer or dispose of assets.

CPB Holdings is required under its credit agreement to maintain a net debt to consolidated EBITDA ratio (as defined in the credit agreement) of not more than 5.00 to 1.0, and a consolidated EBITDA to consolidated interest expense ratio (as defined in the credit agreement) of not less than 2.50 to 1.0. At September 30, 2022, the net debt to consolidated EBITDA ratio was approximately 3.21 to 1.0, and the consolidated EBITDA to consolidated interest expense ratio was approximately 13.19 to 1.0.

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 and nine months ended September 30, 2022, we recorded a reduction to our interest and debt expense of approximately $1.1 million and $2.9 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.

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2023 Senior Note Repayments. During the nine months ended September 30, 2021, we redeemed $687.2 million of principal outstanding under our senior notes due in 2023. In conjunction with the repayment of the notes, we recognized a loss on extinguishment of debt of approximately $6.7 million during the nine months ended September 30, 2021, and paid approximately $8.6 million of accrued interest on our senior notes due in 2023 on the dates they were repurchased. During 2021, we repaid all amounts outstanding under our senior notes due 2023 and funded the repayment using a portion of the proceeds from the issuance of the February 2029 Senior Notes and borrowings under the CMLP Credit Facility.

Note 9 – Commitments and Contingencies

Legal Proceedings

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 related to this matter (including approximately $3.2 million paid during the nine months ended September 30, 2022).

A jury trial concluded on June 17, 2022, and a final judgement was entered on October 24, 2022. The final judgment includes an award of damages of approximately $20.7 million, a pre-judgement interest award of approximately $17.7 million and attorney fees and other costs of approximately $4.7 million. We have insurance coverage related to certain pre-judgement interest awards but have not recorded a receivable related to any potential insurance recovery at September 30, 2022. We expect to appeal the final judgement and, as a result are unable to predict the ultimate 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 September 30, 2022 and December 31, 2021, we had approximately $29.8 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 September 30, 2022 and December 31, 2021, our accrual of approximately $4.2 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

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exposures could range from approximately $4.2 million to $5.2 million at September 30, 2022. Certain of our environmental-related matters are insurable events under our policies and at September 30, 2022, we recorded insurance receivables of approximately $3.7 million.

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
	September 30, 2022		December 31, 2021		September 30, 2022		December 31, 2021
Self-insurance reserves(1)	$	5.4	$	5.5	$	4.5	$	4.7

(1)At September 30, 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 September 30, 2022 and December 31, 2021, we have no amounts accrued for these indemnifications.

Note 10 - Leases

The following table summarizes the balance sheet information related to our operating and finance leases (in millions):

	September 30, 2022		December 31, 2021
Operating Leases
Operating lease right-of-use assets, net	$	18.6	$	27.4
Accrued expenses and other liabilities	$	8.2	$	13.2
Other long-term liabilities	14.5		19.4
Total operating lease liabilities	$	22.7	$	32.6
Finance Leases
Property, plant and equipment	$	14.6	$	12.3
Less: accumulated depreciation	9.5		9.2
Property, plant and equipment, net	$	5.1	$	3.1
Accrued expenses and other liabilities	$	2.2	$	1.7
Other long-term liabilities	2.7		1.2
Total finance lease liabilities	$	4.9	$	2.9

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Lease expense. Our operating lease expense, net totaled $3.4 million and $3.7 million for the three months ended September 30, 2022 and 2021 and $9.2 million and $12.8 million for the nine months ended September 30, 2022 and 2021. Our finance lease expense totaled $0.9 million and $0.8 million for the three months ended September 30, 2022 and 2021 and $2.7 million and $2.6 million for the nine months ended September 30, 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 sold the crude oil railcars to a third party for approximately $24.7 million and we recognized a loss on the sale of approximately $4.1 million during the nine months ended September 30, 2022.

Note 11 – 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 and approximately 20.9 million newly issued CEQP common 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.

On July 11, 2022, we acquired First Reserve’s 50% equity interest in Crestwood Permian in exchange for approximately $5.9 million in cash and approximately 11.3 million newly issued CEQP common units. For a further discussion of the CPJV Acquisition, see Note 3.

On September 15, 2022, CEQP acquired 4.6 million CEQP common units from OMS Holdings LLC, a subsidiary of Chord Energy Corporation (formerly Oasis Petroleum), for approximately $123.7 million. This transaction resulted in CEQP retiring the common units acquired from OMS Holdings LLC.

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 (Crestwood Holdings Transactions). CEQP reflected the purchase price as a reduction to its common unitholders’ partners’ capital in its consolidated statement of partners’ capital during the first quarter of 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 $2.4 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 first quarter of 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 first quarter of 2021.

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Distributions

Crestwood Equity

Limited Partners. A summary of CEQP’s limited partner quarterly cash distributions for the nine months ended September 30, 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
May 6, 2022	May 13, 2022	$	0.655	64.2
August 5, 2022	August 12, 2022	$	0.655	71.6
				$	196.7
2021
February 5, 2021	February 12, 2021	$	0.625	$	46.4
May 7, 2021	May 14, 2021	$	0.625	39.3
August 6, 2021	August 13, 2021	$	0.625	39.3
				$	125.0

On October 20, 2022, we declared a distribution of $0.655 per limited partner unit to be paid on November 14, 2022 to unitholders of record on November 7, 2022 with respect to the quarter ended September 30, 2022.

Preferred Unitholders. During the nine months ended September 30, 2022 and 2021, we paid cash distributions to our preferred unitholders of approximately $45 million in both periods. On October 20, 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 September 30, 2022.

Crestwood Midstream

During the nine months ended September 30, 2022 and 2021, Crestwood Midstream paid cash distributions of $537.6 million and $451.3 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.

On July 11, 2022, Crestwood Midstream received a non-cash contribution of approximately $127.3 million from Crestwood Equity related to the acquisition of its 50% equity interest in Crestwood Permian. In addition, on July 11, 2022, Crestwood Equity contributed cash acquired in conjunction with this acquisition of approximately $149.4 million to Crestwood Midstream.

For a further discussion of these acquisitions, see Note 3.

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.

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The following tables show the change in our non-controlling interest in subsidiary at September 30, 2022 and 2021 (in millions):

Balance at December 31, 2021	$	434.6
Distributions to non-controlling partner	(31.0)
Net income attributable to non-controlling partner	30.8
Balance at September 30, 2022	$	434.4

Balance at December 31, 2020	$	432.7
Contributions from non-controlling partner	1.0
Distributions to non-controlling partner	(29.9)
Net income attributable to non-controlling partner	30.7
Balance at September 30, 2021	$	434.5

In October 2022, Crestwood Niobrara paid cash distributions to Jackalope Holdings of approximately $10.3 million with respect to the quarter ended September 30, 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 September 30, 2022, we had total unamortized compensation expense of approximately $3.8 million related to these performance units. During the three and nine months ended September 30, 2022, we recognized compensation expense of $0.4 million and $1.1 million related to these performance units, which is included in general and administrative expenses on our consolidated statements of operations.

During the nine months ended September 30, 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 nine months ended September 30, 2022 related to those performance units.

Note 12 - 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.

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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 and nine months ended September 30, 2022 and 2021 (in millions):

	Three Months Ended		Nine Months Ended
	September 30,		September 30,
	2022	2021	2022	2021
Preferred units(1)	7.1	7.1	7.1	7.1
Crestwood Niobrara’s preferred units(1)	3.9	3.9	3.9	3.9
Unit-based compensation performance units(1)	0.1	0.2	0.2	0.1
Subordinated units(2)	—	—	—	0.1

(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 its subordinated units. For additional information regarding the retirement of the subordinated units, see Note 11.

Note 13 – Segments

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 Crestwood Permian, Sendero, Oasis Midstream Delaware and Marcellus operations and our Crestwood Permian Basin 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). On July 1, 2022, we sold our Barnett assets which were previously included in our gathering and processing south segment. On July 11, 2022, we acquired Sendero and we reflect its results in our gathering and processing south segment. Also, on July 11, 2022, we acquired First Reserve’s 50% interest in Crestwood Permian, and as a result, we own and control 100% of the equity interests in Crestwood Permian and we reflect its consolidated results in our gathering and processing south segment. Prior to July 11, 2022, our 50% equity method investment in Crestwood Permian was also reflected in our gathering and processing south segment. For a further discussion of these acquisitions and divestiture, see Note 3.

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 gathering, compression, treating and processing services, crude oil gathering and storage services and produced water gathering 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 services and produced water gathering and disposal services to producers in the Delaware and Marcellus 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.

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Below is a reconciliation of CEQP’s and CMLP’s net income (loss) to EBITDA (in millions):

	CEQP								CMLP
	Three Months Ended				Nine Months Ended				Three Months Ended				Nine Months Ended
	September 30,				September 30,				September 30,				September 30,
	2022		2021		2022		2021		2022		2021		2022		2021
Net income (loss)	$	(43.0)	$	(39.6)	$	18.6	$	(116.0)	$	(113.0)	$	(41.8)	$	(107.4)	$	(120.7)
Add:
Interest and debt expense, net	47.6		30.9		123.8		102.0		47.6		30.9		123.8		102.0
Loss on modification/extinguishment of debt	—		—		—		6.7		—		—		—		6.7
Provision for income taxes	1.4		0.1		1.7		0.1		1.4		0.1		1.6		0.1
Depreciation, amortization and accretion	86.9		64.6		242.3		182.6		86.8		68.2		248.0		193.2
EBITDA	$	92.9	$	56.0	$	386.4	$	175.4	$	22.8	$	57.4	$	266.0	$	181.3

The following tables summarize CEQP’s and CMLP’s reportable segment data for the three and nine months ended September 30, 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 $2.5 million and $4.9 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 September 30, 2022 and 2021 and $12.0 million and $182.4 million for the nine months ended September 30, 2022 and 2021.

Segment EBITDA Information

	Three Months Ended September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	272.6	$	177.4	$	1,116.0	$	—	$	1,566.0
Intersegment revenues, net	142.2		137.8		(280.0)		—		—
Costs of product/services sold	230.2		249.6		807.0		—		1,286.8
Operations and maintenance expense	27.4		14.3		13.3		—		55.0
General and administrative expense	—		—		—		32.3		32.3
Loss on long-lived assets, net	—		(247.6)		—		—		(247.6)
Gain on acquisition	—		75.3		—		—		75.3
Earnings from unconsolidated affiliates, net	—		2.0		1.2		—		3.2
Crestwood Midstream EBITDA	$	157.2	$	(119.0)	$	16.9	$	(32.3)	$	22.8
Crestwood Equity
General and administrative expense	—		—		—		1.6		1.6
Gain on long-lived assets	—		71.7		—		—		71.7
Crestwood Equity EBITDA	$	157.2	$	(47.3)	$	16.9	$	(33.9)	$	92.9

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	Three Months Ended September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	144.5	$	26.7	$	1,055.1	$	—	$	1,226.3
Intersegment revenues, net	125.6		—		(125.6)		—		—
Costs of product/services sold	149.7		0.4		949.2		—		1,099.3
Operations and maintenance expense	14.1		5.4		12.1		—		31.6
General and administrative expense	—		—		—		24.4		24.4
Gain (loss) on long-lived assets, net	0.1		(18.6)		—		—		(18.5)
Earnings from unconsolidated affiliates, net	—		4.2		0.7		—		4.9
Crestwood Midstream EBITDA	$	106.4	$	6.5	$	(31.1)	$	(24.4)	$	57.4
Crestwood Equity
General and administrative expense	—		—		—		1.5		1.5
Other income, net	—		—		—		0.1		0.1
Crestwood Equity EBITDA	$	106.4	$	6.5	$	(31.1)	$	(25.8)	$	56.0

	Nine Months Ended September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	787.2	$	243.4	$	3,567.2	$	—	$	4,597.8
Intersegment revenues, net	421.2		137.8		(559.0)		—		—
Costs of product/services sold	686.6		249.6		2,928.2		—		3,864.4
Operations and maintenance expense	78.6		28.6		36.8		—		144.0
General and administrative expense	—		—		—		99.0		99.0
Loss on long-lived assets, net	—		(307.8)		(4.1)		—		(311.9)
Gain on acquisition	—		75.3		—		—		75.3
Earnings from unconsolidated affiliates, net	—		9.4		2.8		—		12.2
Crestwood Midstream EBITDA	$	443.2	$	(120.1)	$	41.9	$	(99.0)	$	266.0
Crestwood Equity
General and administrative expense	—		—		—		4.8		4.8
Gain on long-lived assets(1)	—		125.0		—		—		125.0
Other income, net	—		—		—		0.2		0.2
Crestwood Equity EBITDA	$	443.2	$	4.9	$	41.9	$	(103.6)	$	386.4

(1)Represents the elimination of the loss on long-lived assets of approximately $53 million recorded by CMLP related to the sale of our assets in the Barnett Shale and the gain on long-lived assets of approximately $72 million recorded by CEQP related to this sale. For a further discussion of this transaction, see Note 3.

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	Nine Months Ended September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	422.9	$	76.0	$	2,689.7	$	—	$	3,188.6
Intersegment revenues, net	315.1		—		(315.1)		—		—
Costs of product/services sold	386.4		0.8		2,323.1		—		2,710.3
Operations and maintenance expense	38.2		17.4		34.6		—		90.2
General and administrative expense	—		—		—		61.3		61.3
Gain (loss) on long-lived assets, net	0.2		(19.9)		0.1		—		(19.6)
Earnings (loss) from unconsolidated affiliates, net	—		4.4		(130.3)		—		(125.9)
Crestwood Midstream EBITDA	$	313.6	$	42.3	$	(113.3)	$	(61.3)	$	181.3
Crestwood Equity
General and administrative expense	—		—		—		6.1		6.1
Other income, net	—		—		—		0.2		0.2
Crestwood Equity EBITDA	$	313.6	$	42.3	$	(113.3)	$	(67.2)	$	175.4

Other Segment Information

	CEQP				CMLP
	September 30, 2022		December 31, 2021		September 30, 2022		December 31, 2021
Total Assets
Gathering and Processing North	$	4,072.4	$	2,408.0	$	4,072.4	$	2,408.0
Gathering and Processing South	1,666.4		886.5		1,666.4		1,017.4
Storage and Logistics	1,131.1		1,125.1		1,131.1		1,125.1
Corporate	29.5		26.1		23.7		20.7
Total Assets	$	6,899.4	$	4,445.7	$	6,893.6	$	4,571.2

Note 14 - 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 ASU 2014-09, Revenue from Contracts with Customers (Topic 606) totaled $456.4 million and $331.0 million at September 30, 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):

	September 30, 2022		December 31, 2021
Contract assets (non-current)(1)	$	5.6	$	1.3
Contract liabilities (current)(2)	$	12.2	$	10.7
Contract liabilities (non-current)(2)	$	209.1	$	187.1

(1)Includes approximately $4.7 million acquired in conjunction with the CPJV Acquisition.

(2)During the three and nine months ended September 30, 2022, we recognized revenues of approximately $4.0 million and $11.2 million that were previously included in contract liabilities at December 31, 2021. The remaining change in our contract liabilities during the three and nine months ended September 30, 2022 related to capital reimbursements associated with our revenue contracts and revenue deferrals associated with our contracts with increasing (decreasing) rates.

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The following table summarizes the transaction price allocated to our remaining performance obligations under certain contracts that have not been recognized as of September 30, 2022 (in millions):

Remainder of 2022	$	23.3
2023	70.4
2024	45.8
2025	2.3
2026	0.5
Thereafter	1.3
Total	$	143.6

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 and nine months ended September 30, 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.

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	Three Months Ended September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	33.4	$	10.1	$	—	$	—	$	43.5
Crude oil	14.7		1.7		—		—		16.4
Water	41.8		7.5		—		—		49.3
Processing
Natural gas	20.7		4.8		—		—		25.5
Compression
Natural gas	—		4.7		—		—		4.7
Storage
Crude oil	0.6		—		0.1		—		0.7
NGLs	—		—		2.2		—		2.2
Pipeline
Crude oil	—		—		0.6		—		0.6
NGLs	—		5.2		0.1		(5.2)		0.1
Transportation
Crude oil	1.5		0.1		—		—		1.6
NGLs	—		—		5.0		—		5.0
Product Sales
Natural gas	109.6		144.4		248.4		(205.6)		296.8
Crude oil	120.9		—		362.8		(9.8)		473.9
NGLs	68.3		136.2		411.7		(58.9)		557.3
Water	2.1		—		—		—		2.1
Other	0.8		—		0.2		(0.5)		0.5
Total Topic 606 revenues	414.4		314.7		1,031.1		(280.0)		1,480.2
Non-Topic 606 revenues	0.4		0.5		84.9		—		85.8
Total revenues	$	414.8	$	315.2	$	1,116.0	$	(280.0)	$	1,566.0

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	Three Months Ended September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	13.7	$	21.6	$	—	$	—	$	35.3
Crude oil	17.1		—		—		—		17.1
Water	24.8		—		—		—		24.8
Processing
Natural gas	5.8		1.4		—		—		7.2
Compression
Natural gas	—		3.7		—		—		3.7
Storage
Crude oil	0.1		—		0.1		(0.1)		0.1
NGLs	—		—		2.6		—		2.6
Pipeline
Crude oil	—		—		0.6		—		0.6
Transportation
Crude oil	0.8		—		—		(0.1)		0.7
NGLs	—		—		4.1		—		4.1
Rail Loading
Crude oil	—		—		1.2		—		1.2
Product Sales
Natural gas	42.9		—		84.5		(42.7)		84.7
Crude oil	105.4		—		331.3		(25.1)		411.6
NGLs	59.1		—		500.1		(57.6)		501.6
Other	—		—		0.5		—		0.5
Total Topic 606 revenues	269.7		26.7		925.0		(125.6)		1,095.8
Non-Topic 606 revenues	0.4		—		130.1		—		130.5
Total revenues	$	270.1	$	26.7	$	1,055.1	$	(125.6)	$	1,226.3

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	Nine Months Ended September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	92.2	$	57.0	$	—	$	—	$	149.2
Crude oil	43.6		4.6		—		—		48.2
Water	117.7		13.0		—		—		130.7
Processing
Natural gas	54.8		7.1		—		—		61.9
Compression
Natural gas	—		11.3		—		—		11.3
Storage
Crude oil	1.7		—		0.4		(0.2)		1.9
NGLs	—		—		6.9		—		6.9
Pipeline
Crude oil	—		—		1.5		—		1.5
NGLs	—		5.2		0.2		(5.2)		0.2
Transportation
Crude oil	4.2		0.5		—		(0.1)		4.6
NGLs	—		—		16.3		—		16.3
Rail Loading
Crude oil	—		—		0.4		—		0.4
Product Sales
Natural gas	269.1		145.3		508.0		(331.2)		591.2
Crude oil	394.9		—		1,130.3		(33.9)		1,491.3
NGLs	222.7		136.2		1,505.6		(187.9)		1,676.6
Water	5.0		—		—		—		5.0
Other	1.4		—		0.5		(0.5)		1.4
Total Topic 606 revenues	1,207.3		380.2		3,170.1		(559.0)		4,198.6
Non-Topic 606 revenues	1.1		1.0		397.1		—		399.2
Total revenues	$	1,208.4	$	381.2	$	3,567.2	$	(559.0)	$	4,597.8

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	Nine Months Ended September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	40.5	$	59.5	$	—	$	—	$	100.0
Crude oil	56.2		—		—		—		56.2
Water	69.5		—		—		—		69.5
Processing
Natural gas	17.7		3.8		—		—		21.5
Compression
Natural gas	—		12.1		—		—		12.1
Storage
Crude oil	0.3		—		0.4		(0.3)		0.4
NGLs	—		—		8.7		—		8.7
Pipeline
Crude oil	—		—		2.0		—		2.0
NGLs	—		—		0.1		—		0.1
Transportation
Crude oil	1.9		—		—		(0.1)		1.8
NGLs	—		—		12.5		—		12.5
Rail Loading
Crude oil	—		—		3.4		—		3.4
Product Sales
Natural gas	111.9		0.6		224.4		(111.7)		225.2
Crude oil	297.1		—		926.9		(62.5)		1,161.5
NGLs	142.3		—		1,210.9		(140.5)		1,212.7
Other	—		—		1.4		—		1.4
Total Topic 606 revenues	737.4		76.0		2,390.7		(315.1)		2,889.0
Non-Topic 606 revenues	0.6		—		299.0		—		299.6
Total revenues	$	738.0	$	76.0	$	2,689.7	$	(315.1)	$	3,188.6

Note 15 – 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.

On July 11, 2022, we acquired First Reserve’s 50% equity interest in Crestwood Permian. As a result of this transaction, we control and own 100% of the equity interests of Crestwood Permian and include their results in our consolidated financial statements. Prior to July 11, 2022, we owned a 50% equity interest in Crestwood Permian, which we accounted for under the equity method of accounting, and reflected transactions with Crestwood Permian as transactions with affiliates in the tables below.

As discussed above, in conjunction with our acquisition of First Reserve’s 50% equity interest in Crestwood Permian, we issued 11.3 million newly issued CEQP common units to First Reserve and as a result, First Reserve is considered a related party of CEQP and CMLP. In September 2022, we acquired 4.6 million CEQP common units from a subsidiary of Chord Energy Corporation and as result of this transaction, Chord Energy Corporation is no longer considered a related party of CEQP and CMLP.

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 nine months ended September 30, 2021, we paid approximately $0.6 million of capital expenditures to Applied Consultants, Inc., an affiliate of Crestwood Holdings. In addition, during the nine months ended September 30, 2021,

39

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 nine months ended September 30, 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				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
Revenues at CEQP and CMLP(1)	$	140.8	$	7.1	$	372.7	$	25.2
Costs of product/services sold at CEQP and CMLP(2)	$	51.3	$	34.8	$	232.9	$	101.3
Operations and maintenance expenses at CEQP and CMLP charged to our unconsolidated affiliates(3)	$	2.6	$	5.1	$	12.4	$	16.8
General and administrative expenses charged by CEQP to CMLP, net(4)	$	8.5	$	11.9	$	23.5	$	24.4
General and administrative expenses at CEQP and CMLP(5)	$	—	$	—	$	1.3	$	—

(1)Includes (i) $83.0 million and $218.9 million during the three and nine months ended September 30, 2022 primarily related to the sale of crude oil and NGLs to a subsidiary of Chord Energy Corporation (formerly Oasis Petroleum Inc.); (ii) $57.4 million and $148.6 million during the three and nine months ended September 30, 2022 primarily related to gathering and processing services under agreements with a subsidiary of Chord Energy Corporation (formerly Oasis Petroleum Inc.); (iii) $0.3 million and $3.9 million during the three and nine months ended September 30, 2022 and $7.1 million and $25.2 million during the three and nine months ended September 30, 2021 related to the sale of NGLs to a subsidiary of Crestwood Permian; and (iv) $0.1 million and $1.3 million during the three and nine months ended September 30, 2022 related to compressor leases with a subsidiary of Crestwood Permian;

(2)Includes (i) $41.5 million and $114.1 million during the three and nine months ended September 30, 2022 primarily related to purchases of NGLs from a subsidiary of Chord Energy Corporation (formerly Oasis Petroleum, Inc.); (ii) $9.2 million and $116.8 million during the three and nine months ended September 30, 2022 and $30.4 million and $75.5 million during the three and nine months ended September 30, 2021 related to purchases of natural gas and NGLs from a subsidiary of Crestwood Permian; (iii) $0.3 million and $1.7 million during the three and nine months ended September 30, 2022 and $0.2 million and $11.3 million during the three and nine months ended September 30, 2021 primarily related to purchases of natural gas from a subsidiary of Tres Holdings; (iv) $0.3 million during both the three and nine months ended September 31, 2022 related to gathering services under agreements Crestwood Permian Basin; and (v) $4.2 million and $14.5 million during the three and nine months ended September 30, 2021 related to purchases of NGLs from Ascent Resources - Utica, LLC, an affiliate of Crestwood Holdings.

(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 and nine months ended September 30, 2022, we charged $1.2 million and $3.5 million to Tres Holdings, $1.0 million to Crestwood Permian Basin in both periods and $0.4 million and $7.9 million to Crestwood Permian. During the three and nine months ended September 30, 2021, we charged $0.1 million and $3.4 million to Stagecoach Gas, $1.2 million and $3.6 million to Tres Holdings and $3.8 million and $9.8 million to Crestwood Permian.

(4)Includes $9.6 million and $26.8 million of unit-based compensation charges allocated from CEQP to CMLP during the three and nine months ended September 30, 2022 and $12.9 million and $27.4 million for the three and nine months ended September 30, 2021. In addition, includes $1.1 million and $3.3 million of CMLP’s general and administrative costs allocated to CEQP during the three and nine months ended September 30, 2022 and $1.0 million and $3.0 million for the three and nine months ended September 30, 2021.

(5)Represents general and administrative expenses related to a transition services agreement with Chord Energy Corporation (formerly Oasis Petroleum Inc.).

The following table shows balances with our affiliates which are reflected in our consolidated balance sheets (in millions):

	September 30, 2022		December 31, 2021
Accounts receivable at CEQP and CMLP	$	1.6	$	8.2
Accounts payable at CEQP and CMLP	$	2.2	$	12.0

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Item 2.Management’s Discussion and Analysis of Financial Condition and Results of Operations

Our Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the consolidated financial statements and the accompanying footnotes and Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations in our 2021 Annual Report on Form 10-K.

This report, including information included or incorporated by reference herein, contains forward-looking statements concerning the financial condition, results of operations, plans, objectives, future performance and business of our Company and its subsidiaries. These forward-looking statements include:

•statements that are not historical in nature, including, but not limited to: (i) our belief that anticipated cash from operations, cash distributions from entities that we control, and borrowing capacity under our credit facilities will be sufficient to meet our anticipated liquidity needs for the foreseeable future; (ii) our belief that we do not have material potential liability in connection with legal proceedings that would have a significant financial impact on our consolidated financial condition, results of operations or cash flows; and (iii) our belief that our assets will continue to benefit from the development of unconventional shale plays as significant supply basins; and

•statements preceded by, followed by or that contain forward-looking terminology including the words “believe,” “expect,” “may,” “will,” “should,” “could,” “anticipate,” “estimate,” “intend” or the negation thereof, or similar expressions.

Forward-looking statements are not guarantees of future performance or results. They involve risks, uncertainties and assumptions. Actual results may differ materially from those contemplated by the forward-looking statements due to, among others, the following factors:

•our ability to successfully implement our business plan for our assets and operations;

•governmental legislation and regulations;

•industry factors that influence the supply of and demand for crude oil, natural gas and NGLs;

•industry factors that influence the demand for services in the markets (particularly unconventional shale plays) in which we provide services;

•weather conditions;

•outbreak of illness, pandemic or any other public health crisis, including the COVID-19 pandemic;

•the availability of crude oil, natural gas and NGLs, and the price of those commodities, to consumers relative to the price of alternative and competing fuels;

•the availability of storage for hydrocarbons;

•the ability of members of the Organization of Petroleum Exporting Countries (OPEC) and other oil-producing countries to agree and maintain oil price and production controls;

•economic conditions;

•costs or difficulties related to the integration of acquisitions and success of our joint ventures’ operations;

•environmental claims;

•operating hazards and other risks incidental to the provision of midstream services, including gathering, compressing, treating, processing, fractionating, transporting and storing energy products (i.e., crude oil, NGLs and natural gas) and related products (i.e., produced water);

•interest rates;

•the price and availability of debt and equity financing, including our ability to raise capital through alternatives like joint ventures; and

•the ability to sell or monetize assets, to reduce indebtedness, to repurchase our equity securities, to make strategic investments, or for other general partnership purposes.

For additional factors that could cause actual results to be materially different from those described in the forward-looking statements, see Part I, Item 1A. Risk Factors of our 2021 Annual Report on Form 10-K.

Outlook and Trends

Our business objective is to create long-term value for our unitholders. We expect to create value for our investors by generating stable operating margins and improving cash flows from our diversified midstream operations by prudently financing investments in our assets and expansions of our portfolio, maximizing throughput and optimizing services on our assets, and effectively controlling our capital expenditures, operating and administrative costs.

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We have taken a number of strategic steps to better position the Company as a stronger, better capitalized company that can accretively grow cash flows and as an industry leader in Environmental, Social and Governance (ESG) efforts.

We continue to drive our long-term growth strategy through disciplined capital investments utilizing our current financial flexibility, and on February 1, 2022, we acquired Oasis Midstream in an equity and cash transaction valued at approximately $1.8 billion. Pursuant to the merger agreement, Oasis Petroleum received $150 million in cash plus 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 12.9 million newly issued CEQP common units in exchange for the 14.8 million Oasis Midstream common units held by them. Additionally, under the merger agreement, Oasis Petroleum received a $10 million cash payment for its ownership of the general partner of Oasis Midstream. This transaction further solidifies Crestwood’s competitive position in the Williston Basin with exposure to approximately 1,200 drilling locations and 535,000 dedicated acres and expands the Company’s relationship with Oasis Petroleum. Additionally, Oasis Midstream’s Wild Basin gathering and processing assets are highly complementary with our Arrow gathering system and Bear Den processing facility which provides for immediate opportunities to drive cost savings and commercial synergies and better utilization of available gas processing capacity.

During the third quarter of 2022, we executed a series of strategic transactions including (i) the acquisition of Sendero for approximately $631 million, (ii) the acquisition of First Reserve’s 50% equity interest in Crestwood Permian in exchange for approximately $6 million in cash and approximately 11.3 million CEQP common units, and (iii) the divestitures of our Barnett and Marcellus Shale assets for approximately $290 million and $206 million, respectively. The Sendero Acquisition adds more than 75,000 dedicated acres and over 1,200 existing and new drilling locations in the Delaware Basin. In addition, Sendero’s assets are highly complementary to Crestwood Permian’s Willow Lake system and are being integrated with minimal capital investment, enabling the Company to capture substantial cost and commercial synergies resulting in approximately 550 MMcf/d of processing capacity. The acquisition of Sendero and First Reserve’s 50% equity interest in the Crestwood Permian joint venture significantly increases the Company’s position in the Delaware Basin.

The divestitures of the Cowtown, Lake Arlington and Alliance systems as well as our Marcellus natural gas gathering and compression assets will represent a full exit of our operations in the Barnett and Marcellus Shales. These divestitures allow the Company to focus on building and optimizing its gathering and processing positions in the Williston, Delaware and Powder River Basins which best positions the Company to deliver long-term value to its unitholders.

In addition to the strategic transactions discussed above, we have also taken steps to (i) minimize capital expenditures to better align with development activity by our gathering and processing customers; (ii) realign our organization to reduce operating and administrative expenses; (iii) engage with our customers to maintain volumes across our asset portfolio; (iv) optimize our storage, transportation and marketing assets to take advantage of regional commodity price volatility; and (v) evaluate our debt and equity structure to preserve liquidity and ensure balance sheet strength. Given our efforts over the past few years to improve the Partnership’s competitive position in the businesses we operate, manage costs and improve margins and create a stronger balance sheet, we believe we are well positioned to execute its business plan.

Other Developments

Bakken DAPL Matter. In July 2020, a U.S. District Court (District Court) ordered the Dakota Access Pipeline (DAPL) to cease operation based on an alleged procedural permitting failure. On August 5, 2020, the U.S. Court of Appeals for the District of Columbia Circuit (D.C. Circuit) stayed the DAPL shutdown, and subsequently issued an opinion upholding the District Court’s decision on the merits, but not prohibiting DAPL’s continued operation. The plaintiffs sought another injunction against DAPL’s operation, which was denied by the District Court in May 2021. As required by the District Court, the U.S. Army Corps of Engineers is currently conducting an environmental impact statement, which is currently expected to be complete in 2023. We expect DAPL will remain in operation while the environmental impact statement is being completed.

The Oasis Midstream Wild Basin gathering system connects to the Arrow system and is capable of transporting all of its volumes to the Arrow system. The Arrow gathering system currently connects to the DAPL, Kinder Morgan Hiland, Tesoro and True Companies’ Bridger Four Bears pipelines, providing significant downstream delivery capacity for our Arrow and Wild Basin customers. Additionally, we can transport Arrow and Wild Basin crude volumes to our COLT Hub facility by pipeline or truck, which mitigates the impact of any potential pipeline shut-downs to our producers with the ability to access multiple markets out of the basin.

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Carbon Management. One of the core initiatives related to our ESG efforts surrounds our focus on managing the intensity of our emissions in order to reduce climate-related risk to our business.

In January 2022, we published our first carbon management plan (CMP), which outlines near-term emissions reduction and management activities that we intend to implement over the next three years. The CMP includes several core objectives, including (i) reducing emissions intensity of our assets; (ii) evaluating opportunities to reduce Scope 2 greenhouse gas (GHG) emissions while managing our operations’ energy efficiency; (iii) enhancing our process by which we manage GHG emissions; (iv) piloting methane emission monitoring devices at certain of our facilities; (v) participating in the development of responsibly sourced gas standards for the midstream sector; (vi) investing in technology to better inventory and calculate emissions data and integrating the technology into our operations; and (vii) participating in and providing leadership to trade associations focused on climate-related risks.

We currently believe that our carbon management efforts will help to mitigate the potential impact that emissions may have on our capital expenditures or results of operations in the future, although we currently anticipate that these efforts will not have a material impact on our capital expenditures or results of operations in 2022.

How We Evaluate Our Operations

We evaluate our overall business performance based primarily on EBITDA and Adjusted EBITDA. We do not utilize depreciation, amortization and accretion expense in our key measures because we focus our performance management on cash flow generation and our assets have long useful lives.

EBITDA and Adjusted EBITDA - We believe that EBITDA and Adjusted EBITDA are widely accepted financial indicators of a company’s operational performance and its ability to incur and service debt, fund capital expenditures and make distributions. We believe that EBITDA and Adjusted EBITDA are useful to our investors because it allows them to use the same performance measure analyzed internally by our management to evaluate the performance of our businesses and investments without regard to the manner in which they are financed or our capital structure. EBITDA is defined as income before income taxes, plus debt-related costs (interest and debt expense, net and loss on modification/extinguishment of debt) and depreciation, amortization and accretion expense. Adjusted EBITDA considers the adjusted earnings impact of our unconsolidated affiliates by adjusting our equity earnings or losses from our unconsolidated affiliates to reflect our proportionate share (based on the distribution percentage) of their EBITDA, excluding gains and losses on long-lived assets and other impairments. Adjusted EBITDA also considers the impact of certain significant items, such as unit-based compensation charges, gains or losses on long-lived assets, impairments of goodwill, third party costs incurred related to potential and completed acquisitions, certain environmental remediation costs, the change in fair value of commodity inventory-related derivative contracts, costs associated with the realignment and restructuring of our operations and corporate structure, and other transactions identified in a specific reporting period. The change in fair value of commodity inventory-related derivative contracts is considered in determining Adjusted EBITDA given that the timing of recognizing gains and losses on these derivative contracts differs from the recognition of revenue for the related underlying sale of inventory to which these derivatives relate. Changes in the fair value of other derivative contracts is not considered in determining Adjusted EBITDA given the relatively short-term nature of those derivative contracts. EBITDA and Adjusted EBITDA are not measures calculated in accordance with GAAP, as they do not include deductions for items such as depreciation, amortization and accretion, interest and income taxes, which are necessary to maintain our business. EBITDA and Adjusted EBITDA should not be considered as alternatives to net income, operating cash flow or any other measure of financial performance presented in accordance with GAAP. EBITDA and Adjusted EBITDA calculations may vary among entities, so our computation may not be comparable to measures used by other companies.

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Results of Operations

The following tables summarize our results of operations (in millions):

	Crestwood Equity								Crestwood Midstream
	Three Months Ended				Nine Months Ended				Three Months Ended				Nine Months Ended
	September 30,				September 30,				September 30,				September 30,
	2022		2021		2022		2021		2022		2021		2022		2021
Revenues	$	1,566.0	$	1,226.3	$	4,597.8	$	3,188.6	$	1,566.0	$	1,226.3	$	4,597.8	$	3,188.6
Costs of product/services sold	1,286.8		1,099.3		3,864.4		2,710.3		1,286.8		1,099.3		3,864.4		2,710.3
Operations and maintenance expense	55.0		31.6		144.0		90.2		55.0		31.6		144.0		90.2
General and administrative expense	33.9		25.9		103.8		67.4		32.3		24.4		99.0		61.3
Depreciation, amortization and accretion	86.9		64.6		242.3		182.6		86.8		68.2		248.0		193.2
Loss on long-lived assets, net	175.9		18.5		186.9		19.6		247.6		18.5		311.9		19.6
Gain on acquisition	(75.3)		—		(75.3)		—		(75.3)		—		(75.3)		—
Operating income (loss)	2.8		(13.6)		131.7		118.5		(67.2)		(15.7)		5.8		114.0
Earnings (loss) from unconsolidated affiliates, net	3.2		4.9		12.2		(125.9)		3.2		4.9		12.2		(125.9)
Interest and debt expense, net	(47.6)		(30.9)		(123.8)		(102.0)		(47.6)		(30.9)		(123.8)		(102.0)
Loss on modification/extinguishment of debt	—		—		—		(6.7)		—		—		—		(6.7)
Other income, net	—		0.1		0.2		0.2		—		—		—		—
Provision for income taxes	(1.4)		(0.1)		(1.7)		(0.1)		(1.4)		(0.1)		(1.6)		(0.1)
Net income (loss)	(43.0)		(39.6)		18.6		(116.0)		(113.0)		(41.8)		(107.4)		(120.7)
Add:
Interest and debt expense, net	47.6		30.9		123.8		102.0		47.6		30.9		123.8		102.0
Loss on modification/extinguishment of debt	—		—		—		6.7		—		—		—		6.7
Provision for income taxes	1.4		0.1		1.7		0.1		1.4		0.1		1.6		0.1
Depreciation, amortization and accretion	86.9		64.6		242.3		182.6		86.8		68.2		248.0		193.2
EBITDA	92.9		56.0		386.4		175.4		22.8		57.4		266.0		181.3
Unit-based compensation charges	9.6		12.9		26.8		22.8		9.6		12.9		26.8		22.8
Loss on long-lived assets, net	175.9		18.5		186.9		19.6		247.6		18.5		311.9		19.6
Gain on acquisition	(75.3)		—		(75.3)		—		(75.3)		—		(75.3)		—
(Earnings) loss from unconsolidated affiliates, net	(3.2)		(4.9)		(12.2)		125.9		(3.2)		(4.9)		(12.2)		125.9
Adjusted EBITDA from unconsolidated affiliates, net	5.7		9.8		24.2		56.5		5.7		9.8		24.2		56.5
Change in fair value of commodity inventory-related derivative contracts	(5.4)		46.8		(4.6)		48.9		(5.4)		46.8		(4.6)		48.9
Significant transaction and environmental related costs and other items	9.1		0.8		29.6		1.9		9.1		0.7		29.6		(0.4)
Adjusted EBITDA	$	209.3	$	139.9	$	561.8	$	451.0	$	210.9	$	141.2	$	566.4	$	454.6

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	Crestwood Equity								Crestwood Midstream
	Three Months Ended				Nine Months Ended				Three Months Ended				Nine Months Ended
	September 30,				September 30,				September 30,				September 30,
	2022		2021		2022		2021		2022		2021		2022		2021
Net cash provided by operating activities	$	25.3	$	79.4	$	277.3	$	372.9	$	26.9	$	81.3	$	282.1	$	378.5
Net changes in operating assets and liabilities	129.9		(25.1)		123.9		(114.8)		129.8		(25.3)		123.9		(114.1)
Amortization of debt-related deferred costs	(0.5)		(1.7)		(1.7)		(5.1)		(0.5)		(1.7)		(1.7)		(5.1)
Interest and debt expense, net	47.6		30.9		123.8		102.0		47.6		30.9		123.8		102.0
Unit-based compensation charges	(9.6)		(12.9)		(26.8)		(22.8)		(9.6)		(12.9)		(26.8)		(22.8)
Loss on long-lived assets, net	(175.9)		(18.5)		(186.9)		(19.6)		(247.6)		(18.5)		(311.9)		(19.6)
Gain on acquisition	75.3		—		75.3		—		75.3		—		75.3		—
Earnings (loss) from unconsolidated affiliates, net, adjusted for cash distributions received	0.7		3.6		0.9		(137.5)		0.7		3.6		0.9		(137.5)
Deferred income taxes	(1.2)		0.3		(1.1)		0.4		(1.1)		—		(1.2)		—
Provision for income taxes	1.4		0.1		1.7		0.1		1.4		0.1		1.6		0.1
Other non-cash expense	(0.1)		(0.1)		—		(0.2)		(0.1)		(0.1)		—		(0.2)
EBITDA	92.9		56.0		386.4		175.4		22.8		57.4		266.0		181.3
Unit-based compensation charges	9.6		12.9		26.8		22.8		9.6		12.9		26.8		22.8
Loss on long-lived assets, net	175.9		18.5		186.9		19.6		247.6		18.5		311.9		19.6
Gain on acquisition	(75.3)		—		(75.3)		—		(75.3)		—		(75.3)		—
(Earnings) loss from unconsolidated affiliates, net	(3.2)		(4.9)		(12.2)		125.9		(3.2)		(4.9)		(12.2)		125.9
Adjusted EBITDA from unconsolidated affiliates, net	5.7		9.8		24.2		56.5		5.7		9.8		24.2		56.5
Change in fair value of commodity inventory-related derivative contracts	(5.4)		46.8		(4.6)		48.9		(5.4)		46.8		(4.6)		48.9
Significant transaction and environmental related costs and other items	9.1		0.8		29.6		1.9		9.1		0.7		29.6		(0.4)
Adjusted EBITDA	$	209.3	$	139.9	$	561.8	$	451.0	$	210.9	$	141.2	$	566.4	$	454.6

Segment Results

The following table summarizes the EBITDA of our segments (in millions):

	Three Months Ended						Three Months Ended
	September 30, 2022						September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Gathering and Processing North		Gathering and Processing South		Storage and Logistics
Revenues	$	272.6	$	177.4	$	1,116.0	$	144.5	$	26.7	$	1,055.1
Intersegment revenues	142.2		137.8		(280.0)		125.6		—		(125.6)
Costs of product/services sold	230.2		249.6		807.0		149.7		0.4		949.2
Operations and maintenance expenses	27.4		14.3		13.3		14.1		5.4		12.1
Gain (loss) on long-lived assets, net	—		(247.6)		—		0.1		(18.6)		—
Gain on acquisition	—		75.3		—		—		—		—
Earnings from unconsolidated affiliates, net	—		2.0		1.2		—		4.2		0.7
Crestwood Midstream EBITDA	$	157.2	$	(119.0)	$	16.9	$	106.4	$	6.5	$	(31.1)
Gain on long-lived assets	—		71.7		—		$	—	$	—	$	—
Crestwood Equity EBITDA	$	157.2	$	(47.3)	$	16.9	$	106.4	$	6.5	$	(31.1)

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	Nine Months Ended						Nine Months Ended
	September 30, 2022						September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Gathering and Processing North		Gathering and Processing South		Storage and Logistics
Revenues	$	787.2	$	243.4	$	3,567.2	$	422.9	$	76.0	$	2,689.7
Intersegment revenues	421.2		137.8		(559.0)		315.1		—		(315.1)
Costs of product/services sold	686.6		249.6		2,928.2		386.4		0.8		2,323.1
Operations and maintenance expenses	78.6		28.6		36.8		38.2		17.4		34.6
Gain (loss) on long-lived assets, net	—		(307.8)		(4.1)		0.2		(19.9)		0.1
Gain on acquisition	—		75.3		—		—		—		—
Earnings (loss) from unconsolidated affiliates, net	—		9.4		2.8		—		4.4		(130.3)
Crestwood Midstream EBITDA	$	443.2	$	(120.1)	$	41.9	$	313.6	$	42.3	$	(113.3)
Gain on long-lived assets(1)	—		125.0		—		—		—		—
Crestwood Equity EBITDA	$	443.2	$	4.9	$	41.9	$	313.6	$	42.3	$	(113.3)

(1)Represents the elimination of the loss on long-lived assets of approximately $53 million recorded by CMLP and the gain on long-lived assets of approximately $72 million recorded by CEQP related to the sale of our assets in the Barnett Shale. For a further discussion of the sale of our assets in the Barnett Shale, see Note 3.

Below is a discussion of the factors that impacted EBITDA by segment for the three and nine months ended September 30, 2022 compared to the same periods in 2021.

Gathering and Processing North

EBITDA for our gathering and processing north segment increased by approximately $50.8 million and $129.6 million during the three and nine months ended September 30, 2022 compared to the same periods in 2021. On February 1, 2022, we completed the merger with Oasis Midstream, and as a result, we began reflecting the financial results of Oasis Midstream’s Williston Basin operations in our gathering and processing north segment. For a further discussion of this merger, see Item 1. Financial Statements, Note 3.

Our gathering and processing north segment’s revenues increased by approximately $144.7 million and $470.4 million during the three and nine months ended September 30, 2022 compared to the same periods in 2021, while our costs of product/services sold increased by approximately $80.5 million and $300.2 million during those same periods. During the three and nine months ended September 30, 2022, we recognized revenues of approximately $105.9 million and $261.4 million and product costs of approximately $37.1 million and $84.7 million, respectively, related to our Oasis Midstream Williston Basin operations. The remaining increases in our gathering and processing north segment’s revenues and costs of product/services sold were primarily driven by our Arrow operations which experienced higher average commodity prices on its agreements under which it purchases and sells crude oil and natural gas, partially offset by lower volumes primarily due to lower activity by our producer customers due to the impact that supply chain and other logistical issues had on our customers during the third quarter of 2022, and unusual winter weather conditions experienced during early 2022 that unfavorably impacted our operations and our customers’ operations during the nine months ended September 30, 2022. Arrow’s realized prices on its commodity sales increased by more than 50% during 2022 compared to 2021. Arrow’s natural gas gathering and processing volumes and crude oil gathering volumes decreased by 9%, 7% and 27%, respectively, during the three months ended September 30, 2022 and during the nine months ended September 30, 2022, Arrow’s natural gas gathering and processing volumes and crude oil gathering volumes decreased by 12%, 11% and 31%, respectively, compared to the same periods in 2021.

Our gathering and processing north segment’s operations and maintenance expenses increased by approximately $13.3 million and $40.4 million during the three and nine months ended September 30, 2022 compared to the same periods in 2021, primarily due to our Oasis Midstream Williston Basin operations.

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Gathering and Processing South

EBITDA for CMLP’s gathering and processing south segment decreased by approximately $125.5 million and $162.4 million during the three and nine months ended September 30, 2022 compared to the same periods in 2021. CMLP’s gathering and processing south segment’s EBITDA was impacted by the Sendero and CPJV Acquisitions during the three months ended September 30, 2022, the acquisition of Oasis Midstream’s Delaware Basin operations during the first quarter of 2022, and the Barnett and Marcellus divestitures that impacted both the three months and nine months ended September 30, 2022.

The Sendero and CPJV Acquisitions on July 11, 2022 increased our gathering and processing south segment’s revenues, cost of product/services sold and operations and maintenance expenses by approximately $307.8 million, $257.1 million and $11.1 million, respectively, during the three and nine months ended September 30, 2022. In addition, we recognized a gain of approximately $75.3 million during the three and nine months ended September 30, 2022 related to the CPJV Acquisition, which is further described in Item 1, Financial Statements, Note 3.

In addition to the contributions from our acquisitions described above, the acquisition of Oasis Midstream’s Delaware Basin operations on February 1, 2022 also increased our gathering and processing south segment’s revenues, cost of product/services sold and operations and maintenance expenses by approximately $4.9 million, $0.2 million and $1.5 million, respectively, during the three months ended September 30, 2022, and approximately $13.7 million, $0.5 million and $3.4 million, respectively, during the nine months ended September 30, 2022.

The divestiture of our Barnett operations on July 1, 2022 decreased the gathering and processing south segment’s revenues, cost of product/services sold and operations and maintenance expenses by approximately $16.0 million, $0.3 million and $3.8 million, respectively, during the three months ended September 30, 2022. CMLP also recognized a $53.3 million loss on long-lived assets related to the Barnett divestiture and a $248.2 million loss on long-lived assets related to the Marcellus divestiture during the second and third quarters of 2022, respectively, which are further described in Item 1, Financial Statements, Note 3.

The remaining change in our gathering and processing south segment’s revenues and costs of product/services sold during the nine months ended September 30, 2022 compared to the same period in 2021, primarily related to our Barnett operations, which experienced higher revenues and costs of products sold during the first half of 2022 due to the impact that higher commodity prices had on their percentage-of-index contracts.

Also impacting our gathering and processing south segment’s EBITDA during the nine months ended September 30, 2022 was a loss on long-lived assets of approximately $7.0 million related to the anticipated sale of parts inventory related to our legacy Granite Wash operations.

The CPJV Acquisition resulted in a decrease in earnings from unconsolidated affiliates of approximately $2.9 million during the three months ended September 30, 2022 compared to the same period in 2021, due to the consolidation of this equity method investment in July 2022, partially offset by an increase in equity earnings of approximately $0.7 million during the three and nine months ended September 30, 2022 related to the Crestwood Permian Basin equity investment acquired in conjunction with the CPJV Acquisition. The remaining increase in our equity earnings during the nine months ended September 30, 2022 compared to the same period in 2021, related to the Crestwood Permian equity investment which experienced an increase in its natural gas gathering and processing revenues as a result of an increase of over 100% of its gathering and processing volumes, which was driven by higher demand for its services due to higher commodity prices experienced in the first half of 2022 compared to the same period in 2021.

EBITDA for CEQP’s gathering and processing south segment decreased by approximately $53.8 million and $37.4 million during the three and nine months ended September 30, 2022 compared to the same periods in 2021. The change in CEQP’s gathering and processing south segment’s EBITDA period over period was due to all of the factors discussed above for CMLP. However, CEQP did not record a loss on long-lived assets during the nine months ended September 30, 2022 related to the divestiture of the Barnett assets due to historical impairments previously recorded on Barnett’s property, plant and equipment by CEQP. During the three months ended September 30, 2022, CEQP recorded a gain on the Barnett divestiture of approximately $72 million. For a further discussion of the Barnett divestiture, see Item 1. Financial Statements, Note 3.

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Storage and Logistics

EBITDA for our storage and logistics segment increased by approximately $48.0 million and $155.2 million during the three and nine months ended September 30, 2022 compared to the same periods in 2021. Our storage and logistics segment’s EBITDA for the three and nine months ended September 30, 2021 was impacted by a reduction to the equity earnings from our Stagecoach Gas equity method investment as a result of recording our proportionate share of a loss on long-lived assets (including goodwill) recorded by the equity method investee as further discussed below.

Our storage and logistics segment’s revenues decreased by approximately $93.5 million during the three months ended September 30, 2022 compared to the same period in 2021, while our costs of product/services sold decreased by approximately $142.2 million during the same period. During the nine months ended September 30, 2022, our storage and logistics segment’s revenues increased by approximately $633.6 million compared to the same period in 2021, while our costs of product/services sold increased by approximately $605.1 million during the same period.

Our NGL marketing and logistics operations experienced a decrease in revenues and costs of product/services sold of approximately $132.2 million and $187.7 million, respectively, during the three months ended September 30, 2022 compared to the same period in 2021. These decreases were primarily driven by lower NGL marketing, storage and terminalling services during 2022 compared to 2021 as a result of continued backwardation in NGL prices and the easing of market infrastructure constraints that impacted demand for our services. Our NGL marketing and logistics operations experienced an increase in revenues of approximately $351.0 million and an increase in costs of product/services sold of approximately $314.7 million during the nine months ended September 30, 2022 compared to the same period in 2021. These increases were primarily driven by higher NGL prices as a result of overall increases in commodity prices during 2022 compared to 2021. Our NGL marketing and logistics operations’ costs of product/services sold was also impacted by the effect of increasing commodity prices on our assets and liabilities from price risk management activities. Included in our costs of product/services sold was a gain of $45.0 million and a loss of $6.3 million during the three and nine months ended September 30, 2022, and a loss of $53.4 million and $94.8 million during the three and nine months ended September 30, 2021 related to our price risk management activities.

Our crude oil and natural gas marketing operations experienced an increase in revenues of approximately $40.4 million and $287.8 million during the three and nine months ended September 30, 2022, compared to the same periods in 2021, and an increase in product costs of approximately $45.3 million and $290.0 million during those same periods. These increases were primarily driven by higher crude oil purchases and sales as a result of increases in commodity prices during 2022 compared to 2021, as well as an increase in marketing activity surrounding our natural gas-related operations driven by higher natural gas prices.

Our storage and logistics segment’s EBITDA was impacted by a loss on long-lived assets of approximately $4.1 million during the nine months ended September 30, 2022 primarily due to the buyout of leases related to our exiting the crude oil railcar leasing business. For a further discussion of this matter, see Item 1. Financial Statements, Note 10.

Our storage and logistics segment’s EBITDA was also impacted by a net increase in earnings from unconsolidated affiliates of approximately $133.1 million during the nine months ended September 30, 2022 compared to the same period in 2021. During the nine months ended September 30, 2021, our results included a loss from unconsolidated affiliates of approximately $139.4 million from our Stagecoach Gas equity investment that was sold in mid-2021. This loss primarily related to a $155.4 million reduction to the equity earnings recorded during the nine months ended September 30, 2021 as a result of recording our proportionate share of a loss on long-lived assets (including goodwill) recorded by the equity method investee. In addition, our earnings from unconsolidated affiliates during the nine months ended September 30, 2021 were also reduced by our proportionate share of transaction costs of approximately $3.0 million related to the sale of the Stagecoach Gas equity investment. For a further discussion of this matter, see Item 1. Financial Statements, Note 5. During the three months ended September 30, 2022, earnings from our Tres Holdings equity investment increased by $1.4 million compared to the same period in 2021, primarily due to its ability to capture additional storage and transportation opportunities as a result of higher natural gas prices during 2022 compared to 2021. During the nine months ended September 30, 2022, earnings from our Tres Holdings equity investment decreased by $5.9 million compared to the same period in 2021. During the nine months ended September 30, 2021, Tres Holdings experienced higher revenues from natural gas inventory sales and an increase in demand for its storage and transportation services as a result of the unusually cold weather experienced during early 2021.

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Other EBITDA Results

General and Administrative Expenses. During the three and nine months ended September 30, 2022, our general and administrative expenses increased compared to the same periods in 2021, primarily due to transaction costs incurred in conjunction with our strategic transactions executed during 2022 discussed in Item 1. Financial Statements, Note 3. In addition, we also experienced higher unit-based compensation charges during the nine months ended September 30, 2022 compared to the same period in 2021, primarily due to higher average awards outstanding under our long-term incentive plans.

Items not affecting EBITDA include the following:

Depreciation, Amortization and Accretion Expense. During the three and nine months ended September 30, 2022, our depreciation, amortization and accretion expense increased compared to the same periods in 2021, primarily due to our acquisitions during 2022, partially offset by the divestiture of our Barnett Shale assets in July 2022. See Item 1. Financial Statements, Note 3 for a further discussion of these transactions.

Interest and Debt Expense, Net. During the three and nine months ended September 30, 2022, our interest and debt expense, net increased primarily due to the April 2029 Senior Notes assumed in conjunction with the merger with Oasis Midstream and the CPBH Credit Facility assumed in conjunction with the acquisition of the 50% equity interest in Crestwood Permian. In addition, our interest and debt expense increased due to borrowings under the CMLP Credit Facility to fund the cash consideration in conjunction with the Oasis Midstream, Sendero and Crestwood Permian acquisitions and to fund the repayment of the Oasis Midstream credit facility assumed in conjunction with the Oasis Merger. For a further discussion of the April 2029 Senior Notes and the CPBH Credit Facility, see Item 1. Financial Statements, Note 8.

The following table provides a summary of interest and debt expense (in millions):

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
Credit facilities	$	12.8	$	3.1	$	21.5	$	12.0
Senior notes	35.2		26.1		102.4		82.9
Other	0.5		1.8		1.8		7.4
Gross interest and debt expense	48.5		31.0		125.7		102.3
Less: capitalized interest	0.9		0.1		1.9		0.3
Interest and debt expense, net	$	47.6	$	30.9	$	123.8	$	102.0

Loss on Extinguishment of Debt. During the nine months ended September 30, 2021, we recognized a loss on extinguishment of debt of approximately $6.7 million in conjunction with the redemption of our 2023 Senior Notes.

Liquidity and Sources of Capital

Crestwood Equity is a holding company that derives all of its operating cash flow from its operating subsidiaries. Our principal sources of liquidity include cash generated by operating activities from our subsidiaries, distributions from our joint ventures, borrowings under our credit facilities, and sales of equity and debt securities. Our equity investments use cash from their respective operations and contributions from us to fund their operating activities and maintenance and growth capital expenditures. We believe our liquidity sources and operating cash flows are sufficient to address our future operating, debt service and capital requirements.

We make quarterly cash distributions to our common unitholders within approximately 45 days after the end of each fiscal quarter in an aggregate amount equal to our available cash for such quarter. We also pay quarterly cash distributions of approximately $15 million to our preferred unitholders and quarterly cash distributions of approximately $10 million to Crestwood Niobrara LLC’s non-controlling partner.

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On October 20, 2022, we declared a quarterly cash distribution of $0.655 per unit to our common unitholders with respect to the third quarter of 2022, which will be paid on November 14, 2022. Our Board of Directors evaluates the level of distributions to our common and preferred unitholders every quarter and considers a wide range of strategic, commercial, operational and financial factors, including current and projected operating cash flows. We believe our operating cash flows will exceed cash distributions to our partners, preferred unitholders and non-controlling partner, and as a result, we will have adequate operating cash flows as a source of liquidity for our growth capital expenditures.

On September 15, 2022, Crestwood Equity acquired 4.6 million CEQP common units from OMS Holdings LLC, a subsidiary of Chord Energy Corporation (formerly Oasis Petroleum Inc.), for approximately $123.7 million. This transaction resulted in Crestwood Equity retiring the common units acquired from OMS Holdings LLC. The acquisition of these CEQP common units did not impact the common unit repurchase program described below.

In March 2021, Crestwood Equity’s board of directors authorized a $175 million common unit and preferred unit repurchase program effective through December 31, 2022. Pursuant to the program, we may purchase common and preferred units from time to time in the open market in accordance with applicable securities laws at current market prices. The timing and amount of purchases under the program will be determined based on growth capital opportunities, financial performance and outlook, and other factors, including acquisition opportunities and market conditions. The unit repurchase program does not obligate us to purchase any specific dollar amount or number of units and may be suspended or discontinued at any time.

In conjunction with the acquisition of the First Reserve’s 50% equity interest in Crestwood Permian, we assumed Crestwood Permian’s credit facility, which provides for revolving loans, letters of credit and swing line loans in an aggregate principal amount of up to $230 million. In addition, the CPBH Credit Facility has an accordion feature that allows Crestwood Permian to increase the available borrowings under the facility by up to an additional $85 million, subject to certain conditions. Upon the closing of the merger with Oasis Midstream on February 1, 2022, the CMLP Credit Facility was increased to $1.5 billion. In October 2022, we amended the CMLP Credit Facility to increase the capacity of the facility from $1.5 billion to $1.75 billion under the terms of the credit agreement. As of September 30, 2022, we had $382.6 million and $13.3 million of available capacity under the CMLP Credit Facility and CPBH Credit Facility, respectively, considering the most restrictive debt covenants in the respective credit agreements. As of September 30, 2022, we were in compliance with all of our debt covenants applicable to our credit facilities and senior notes. See Part I, Item 1. Financial Statements, Note 8 for a description of the covenants related to our credit facilities.

We may from time to time seek to retire or purchase our outstanding debt through cash purchases and/or exchanges for equity securities, in open market purchases, privately negotiated transactions, tender offers or otherwise. Such repurchases or exchanges, if any, will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors. The amounts involved may be material.

Cash Flows

The following table provides a summary of Crestwood Equity’s cash flows by category (in millions):

	Nine Months Ended
	September 30,
	2022		2021
Net cash provided by operating activities	$	277.3	$	372.9
Net cash provided by (used in) investing activities	$	(517.2)	$	582.9
Net cash provided by (used in) financing activities	$	233.0	$	(955.5)

Operating Activities

Our operating cash flows decreased by approximately $95.6 million during the nine months ended September 30, 2022 compared to the same period in 2021. The decrease was primarily driven by a $148.3 million net increase in the fair value of our price risk management activities during the nine months ended September 30, 2022 compared to a $189.1 million net decrease in the fair value of our price risk management activities during the nine months ended September 30, 2021 as a result of changes in commodity prices. Partially offsetting this decrease was higher revenues of approximately $1,409.2 million, partially offset by higher costs of product/services sold of approximately $1,154.1 million primarily from our storage and logistics and gathering and processing north segments as discussed Results of Operations above.

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Investing Activities

Acquisitions and Divestiture. During the nine months ended September 30, 2022, we completed the following acquisitions and divestiture. For a further discussion of these transactions, see Item 1. Financial Statements, Note 3.

•Oasis Merger. On February 1, 2022, we completed the merger with Oasis Midstream, which was valued at approximately $1.8 billion. We paid cash consideration of $160 million, net of cash acquired of approximately $14.9 million, and issued approximately 33.8 million CEQP common units to Oasis Midstream’s unitholders.

•Sendero Acquisition. On July 11, 2022, we acquired Sendero for cash consideration of approximately $631.2 million, net of cash acquired of approximately $28.5 million.

•CPJV Acquisition. On July 11, 2022, we acquired First Reserve’s 50% equity interest in Crestwood Permian in exchange for approximately $5.9 million in cash and approximately 11.3 million newly issued CEQP common units. We also acquired cash of approximately $149.4 million in conjunction with this acquisition.

•Barnett Divestiture. On July 1, 2022, we sold our assets in the Barnett Shale to EnLink for approximately $290 million.

Capital Expenditures. The energy midstream business is capital intensive, requiring significant investments for the acquisition or development of new facilities. We categorize our capital expenditures as either:

•growth capital expenditures, which are made to construct additional assets, expand and upgrade existing systems, or acquire additional assets; or

•maintenance capital expenditures, which are made to replace partially or fully depreciated assets, to maintain the existing operating capacity of our assets, extend their useful lives or comply with regulatory requirements.

As a result of the series of strategic transactions executed during the third quarter of 2022, which include the acquisitions of Sendero and the remaining 50% equity interest in Crestwood Permian and the divestitures of our assets in the Barnett and Marcellus shales, we currently estimate that our growth capital expenditures for the remainder of 2022 will be approximately $200 million to $220 million. In addition, we expect to spend between approximately $25 million and $30 million on maintenance capital expenditures and approximately $5 million to $15 million on capital expenditures that are directly reimbursable by our customers. Our growth capital expenditures during the year will increase the services we can provide to our customers and the operating efficiencies of our systems. We expect to finance our capital expenditures with a combination of cash generated by our operating subsidiaries, distributions received from our equity investments and borrowings under our credit facilities. Additional commitments or expenditures will be made at our discretion, and any discontinuation of these construction projects could result in less future operating cash flows and earnings.

The following table summarizes our capital expenditures for the nine months ended September 30, 2022 (in millions):

Growth capital(1)	$	125.9
Maintenance capital	15.2
Other(2)	6.2
Purchases of property, plant and equipment	$	147.3

(1)Includes $3.2 million paid related to outstanding litigation on the construction of the Bear Den II cryogenic processing plant.

(2)Represents purchases of property, plant and equipment that are reimbursable by third parties.

Investments in Unconsolidated Affiliates. During the nine months ended September 30, 2022 and 2021, we contributed approximately $6.7 million and $6.9 million to our Tres Holdings equity investment primarily for its operating purposes. During the nine months ended September 30, 2022 and 2021, we contributed approximately $83.5 million and $3.3 million to our Crestwood Permian equity investment prior to our acquisition of the remaining 50% equity interest in Crestwood Permian from First Reserve.

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Financing Activities

The following equity and debt transactions impacted our financing activities during the nine months ended September 30, 2022:

Equity and Debt Transactions

•During the nine months ended September 30, 2022, CEQP acquired 4.6 million CEQP common units from OMS Holdings LLC, a subsidiary of Chord Energy Corporation for approximately $123.7 million;

•During the nine months ended September 30, 2022, distributions to our partners increased by approximately $71.7 million compared to the same period in 2021, primarily due to an increase in common units outstanding as a result of the units issued in conjunction with the merger with Oasis Midstream and the CPJV Acquisition, as well as an increase in our distribution per limited partner unit from $0.625 per unit to $0.655 per unit;

•During the nine months ended September 30, 2022, our taxes paid for unit-based compensation vesting increased by approximately $7.5 million compared to the same period in 2021, primarily due to higher vesting of unit-based compensation awards;

•During the nine months ended September 30, 2022, we borrowed amounts under the CMLP Credit Facility to (i) fund cash consideration of approximately $631.2 million to acquire Sendero; (ii) fund approximately $5.9 million of cash consideration to acquire the remaining 50% equity interest in Crestwood Permian; (iii) fund $160.0 million of cash consideration paid in conjunction with the Oasis Merger; and (iv) repay approximately $218.4 million outstanding under the Oasis Midstream credit facility assumed in conjunction with the Oasis Merger;

•During the nine months ended September 30, 2021, CEQP paid approximately $275.6 million in conjunction with the Crestwood Holdings Transactions;

•During the nine months ended September 30, 2021, we paid approximately $690.5 million to repurchase and cancel approximately $687.2 million of our senior notes that were due in 2023;

•During the nine months ended September 30, 2021, we received net proceeds of approximately $691 million from the issuance of our senior notes due February 2029; and

•During the nine months ended September 30, 2022, our other debt-related transactions resulted in net repayments under our CMLP Credit Facility and our CPBH Credit Facility of $243.7 million compared to net repayments of $471.1 million during the same period in 2021.

Guarantor Summarized Financial Information

Crestwood Midstream and Crestwood Midstream Finance Corp. are issuers of our CMLP debt securities (the Issuers). Crestwood Midstream is a holding company and owns no operating assets and has no significant operations independent of its subsidiaries. Crestwood Midstream Finance Corp. is Crestwood Midstream’s 100% owned subsidiary and has no material assets or operations other than those related to its service as co-issuer of our senior notes. Obligations under Crestwood Midstream’s senior notes are jointly and severally guaranteed by substantially all of its subsidiaries (collectively, the Guarantor Subsidiaries), except for Crestwood Infrastructure Holdings LLC, Crestwood Niobrara LLC, Crestwood Pipeline and Storage Northeast LLC, Powder River Basin Industrial Complex LLC, and Tres Palacios Holdings LLC and their respective subsidiaries (collectively, Non-Guarantor Subsidiaries). The assets and credit of our Non-Guarantor Subsidiaries are not available to satisfy the debts of the Issuers or Guarantor Subsidiaries, and the liabilities of our Non-Guarantor Subsidiaries do not constitute obligations of the Issuers or Guarantor Subsidiaries. For additional information regarding our senior notes and related guarantees, see our 2021 Annual Report on Form 10-K and Item 1. Financial Statements, Note 8 of this Quarterly Report on Form 10-Q.

The following tables provide summarized financial information for the Issuers and Guarantor Subsidiaries (collectively, the Obligor Group) on a combined basis after elimination of significant intercompany balances and transactions between entities in the Obligor Group. The investment balances in the Non-Guarantor Subsidiaries have been excluded from the supplemental summarized combined financial information. Transactions with other related parties, including the Non-Guarantor Subsidiaries, represent affiliate transactions and are presented separately in the summarized combined financial information below.

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Summarized Combined Balance Sheet Information (in millions)

	September 30, 2022		December 31, 2021
Current assets	$	901.0	$	574.3
Current assets - affiliates	$	1.3	$	8.4
Property, plant and equipment, net	$	3,194.4	$	2,161.5
Non-current assets	$	1,115.5	$	642.3
Current liabilities	$	558.7	$	578.9
Current liabilities - affiliates	$	78.2	$	14.7
Long-term debt, less current portion	$	3,353.3	$	2,052.1
Non-current liabilities	$	146.8	$	138.7

Summarized Combined Statement of Operations Information (in millions)

	Nine Months Ended September 30, 2022
Revenues	$	4,093.9
Revenues - affiliates	$	376.4
Cost of products/services sold	$	3,330.3
Cost of products/services sold - affiliates	$	358.7
Operations and maintenance expenses(1)	$	121.1
General and administrative expenses(2)	$	99.0
Operating income	$	51.4
Net loss	$	(72.4)

(1)    We have operating agreements with certain of our 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 nine months ended September 30, 2022, we charged $22.7 million to our affiliates under these agreements.

(2)    Includes $23.5 million of net general and administrative expenses that were charged by our affiliates to us.

Item 3.Quantitative and Qualitative Disclosures About Market Risk

Our interest rate risk and commodity price, market and credit risks are discussed in our 2021 Annual Report on Form 10-K. There have been no material changes in those exposures from December 31, 2021 to September 30, 2022.

Item 4.Controls and Procedures

Disclosure Controls and Procedures

As of September 30, 2022, Crestwood Equity and Crestwood Midstream carried out an evaluation under the supervision and with the participation of their respective management, including the Chief Executive Officer and Chief Financial Officer of their General Partners, as to the effectiveness, design and operation of our disclosure controls and procedures (as defined in the Securities Exchange Act of 1934, as amended (Exchange Act) Rules 13a-15(e) and 15d-15(e)). Crestwood Equity and Crestwood Midstream maintain controls and procedures designed to provide reasonable assurance that information required to be disclosed in their respective reports that are filed or submitted under the Exchange Act of 1934, as amended, are recorded, processed, summarized and reported within the time periods specified by the rules and forms of the SEC, and that information is accumulated and communicated to their respective management, including the Chief Executive Officer and Chief Financial Officer of their General Partners, as appropriate, to allow timely decisions regarding required disclosure. Such management, including the Chief Executive Officer and Chief Financial Officer of their General Partners, do not expect that the disclosure controls and procedures or the internal controls will prevent and/or detect all errors and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Crestwood Equity’s and Crestwood Midstream’s disclosure controls and procedures are designed to provide reasonable assurance of achieving their objectives and the Chief Executive Officer and

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Chief Financial Officer of their General Partners concluded that our disclosure controls and procedures were effective at the reasonable assurance level as of September 30, 2022.

Changes in Internal Control over Financial Reporting

On February 1, 2022, we completed the merger with Oasis Midstream and on July 11, 2022, we completed the Sendero Acquisition and the CPJV Acquisition. As a result, we have extended our controls and procedures surrounding our internal control processes over financial reporting to include Oasis Midstream’s, Sendero’s and Crestwood Permian’s operations. Except for these matters, there were no changes to Crestwood Equity’s or Crestwood Midstream’s internal control over financial reporting during the three and nine months ended September 30, 2022 that have materially affected, or are reasonably likely to materially affect Crestwood Equity’s or Crestwood Midstream’s internal control over financial reporting.

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PART II – OTHER INFORMATION

Item 1.Legal Proceedings

Part I, Item 1. Financial Statements, Note 9 to the Consolidated Financial Statements, of this Form 10-Q is incorporated herein by reference.

Item 1A.Risk Factors

Our business faces many risks. Any of the risks discussed elsewhere in this Form 10-Q or our other SEC filings could have a material impact on our business, financial position or results of operations. Additional risks and uncertainties not presently known to us or that we currently believe to be immaterial may also impair our business operations. For a detailed discussion of the risk factors that should be understood by any investor contemplating investment in our common units, see Part I, Item 1A. Risk Factors in our 2021 Annual Report on Form 10-K.

Item 2.Unregistered Sales of Equity Securities and Use of Proceeds

On September 15, 2022, CEQP acquired 4.6 million CEQP common units from OMS Holdings LLC, a subsidiary of Chord Energy, for approximately $123.7 million. This transaction resulted in CEQP retiring the common units acquired from OMS Holdings LLC. The acquisition of these CEQP common units did not impact the $175 million common unit repurchase program announced in March 2021.

The table below presents CEQP’s common unit repurchase activity for the three months ended September 30, 2022:

	Total Number of Units Repurchased(1)	Weighted-Average Price Paid Per Unit		Units Purchased as Part of Publicly Announced Programs	Maximum Dollar Value That May Yet Be Repurchased Under the Program
July 1, 2022 - July 31, 2022	—	$	—	—	$	—
August 1, 2022 - August 31, 2022	—	—		—	—
September 1, 2022 - September 30, 2022	4,600,000	26.90		—	—
Totals / Weighted Average	4,600,000	$	26.90	—	$	—

(1)    All units repurchased during the three months ended September 30, 2022 were purchased pursuant to a Common Unit Repurchase Agreement. For more information on this transaction, see Part I, Item I. Financial Statements, Note 11.

Item 3.Defaults Upon Senior Securities

None.

Item 4.Mine Safety Disclosures

Not applicable.

Item 5.Other Information

None.

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Item 6.Exhibits

Exhibit Number	Description
2.1	Purchase and Sale Agreement, dated as of May 31, 2021 among Con Edison Gas Pipeline and Storage Northeast, LLC, Crestwood Pipeline and Storage Northeast LLC, as the Sellers, Stagecoach Gas Services LLC as the Company, Kinder Morgan Operating LLC “A” as Buyer, Con Edison Transmission, Inc. (solely for the limited purposes set forth therein) and Crestwood Midstream Partners LP (solely for the limited purposes set forth therein) (incorporated by reference to Exhibit 2.1 to Crestwood Equity Partners LP’s Form 8-K filed on June 1, 2021)
2.2	Equity Purchase Agreement, dated as of May 25, 2022, by and among Sendero Midstream Partners, LP, Energy Capital Partners III, LP, Energy Capital Partners III-A, LP, Energy Capital Partners III-B (Sendero IP), LP, Energy Capital Partners III-C (Sendero IP), LP, Carlsbad Co-Invest, LP, ECP III (Sendero Co-Invest) Corp, Sendero Midstream Management, LLC, Sendero Midstream GP, LLC, Crestwood Midstream Partners LP, Crestwood Sendero GP LLC, and Crestwood Equity Partners LP (solely for the limited purposes set forth therein) (incorporated by reference to Exhibit 2.1 to Crestwood Equity Partners LP’s Form 8-K filed on May 26, 2022)
2.3	Contribution Agreement, dated as of May 25, 2022, by and between FR XIII Crestwood Permian Basin Holdings LLC and Crestwood Equity Partners LP (incorporated by reference to Exhibit 2.2 to Crestwood Equity Partners LP’s Form 8-K filed on May 26, 2022)
3.1	Certificate of Limited Partnership of Inergy, L.P. (incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Registration Statement on Form S-1 filed on March 14, 2001)
3.2	Certificate of Correction of Certificate of Limited Partnership of Inergy, L.P. (incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Form 10-Q filed on May 12, 2003)
3.3	Amendment to the Certificate of Limited Partnership of Crestwood Equity Partners LP (the “Company”) (f/k/a Inergy, L.P.) dated as of October 7, 2013 (incorporated herein by reference to Exhibit 3.2 to Crestwood Equity Partners LP's Form 8-K filed on October 10, 2013)
3.4	Certificate of Formation of Inergy GP, LLC (incorporated by reference to Exhibit 3.5 to Inergy, L.P.'s Registration Statement on Form S-1/A filed on May 7, 2001)
3.5	Certificate of Amendment of Crestwood Equity GP LLC (the “General Partner”) (f/k/a Inergy GP, LLC) dated as of October 7, 2013 (incorporated by reference to Exhibit 3.3A to Crestwood Equity Partners LP's Form 10-Q filed on November 8, 2013)
3.6	First Amended and Restated Limited Liability Company Agreement of Inergy GP, LLC dated as of September 27, 2012 (incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Form 8-K filed on September 27, 2012)
3.7	Amendment No. 1 to the First Amended and Restated Limited Liability Company Agreement of the General Partner entered into and effective as of October 7, 2013 (incorporated by reference to Exhibit 3.4A to Crestwood Equity Partners LP's Form 10-Q filed on November 8, 2013)
3.8	Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP dated as of April 11, 2014 (incorporated herein by reference to Exhibit 3.1 to Crestwood Equity Partners LP's Form 8-K filed on April 11, 2014)
3.9	First Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of September 30, 2015 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partner LP’s Form 8-K filed on October 1, 2015)
3.10	Second Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of November 8, 2017 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partners LP’s Form 8-K filed on November 13, 2017)
3.11	Third Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of May 30, 2018 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partners LP’s Form 8-K filed on June 4, 2018)
3.12	Second Amended and Restated Agreement of Limited Partnership of Crestwood Midstream Partners LP, dated as of September 30, 2015 (incorporated by reference to Exhibit 3.1 to Crestwood Midstream Partners LP's Form 8-K filed on October 1, 2015)
3.13	Certificate of Formation of NRGM GP, LLC (incorporated herein by reference to Exhibit 3.7 to Inergy Midstream, L.P.'s Form S-1/A filed on November 21, 2011)

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3.14	Amended and Restated Limited Liability Company Agreement of NRGM GP, LLC, dated December 21, 2011 (incorporated herein by reference to Exhibit 3.2 to Inergy Midstream, L.P.'s Form 8-K filed on December 22, 2011)
3.15	Amendment No. 1 to the Amended and Restated Limited Liability Company Agreement of Crestwood Midstream GP LLC (f/k/a NRGM GP, LLC) (incorporated herein by reference to Exhibit 3.39 to Crestwood Midstream Partners LP's Form S-4/A filed on October 28, 2013)
3.16	Fourth Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of June 28, 2019 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partners LP’s Form 8-K filed on June 28, 2019)
3.17	Sixth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP dated August 20, 2021 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partners LP’s Form 8-K filed on August 20, 2021)
3.18	Second Amended and Restated Limited Liability Company Agreement of Crestwood Equity GP LLC dated August 20, 2021 (incorporated by reference to Exhibit 3.2 to Crestwood Equity Partners LP’s Form 8-K on August 20, 2021)
10.1	Underwriting Agreement dated September 12, 2022 by and among Crestwood Equity Partners LP, Oasis Investment Holdings LLC, OMS Holdings LLC and Citigroup Global Markets Inc., as representative of the underwriter named in Schedule 2 thereto (incorporated by reference to Exhibit 1.1 to Crestwood Equity Partners LP’s Form 8-K filed on September 15, 2022)
10.2	Common Unit Purchase Agreement dated September 12, 2022 by and between Crestwood Equity Partners LP and OMS Holdings LLC (incorporated by reference to Exhibit 10.1 to Crestwood Equity Partners LP’s Form 8-K filed on September 15, 2022)
*31.1	Certification of Chief Executive Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, as amended - Crestwood Equity Partners LP
*31.2	Certification of Chief Financial Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, as amended - Crestwood Equity Partners LP
*31.3	Certification of Chief Executive Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, as amended - Crestwood Midstream Partners LP
*31.4	Certification of Chief Financial Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, as amended - Crestwood Midstream Partners LP
*32.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 - Crestwood Equity Partners LP
*32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 - Crestwood Equity Partners LP
*32.3	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 - Crestwood Midstream Partners LP
*32.4	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 - Crestwood Midstream Partners LP
**101.INS	Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
**101.SCH	Inline XBRL Taxonomy Extension Schema Document
**101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase Document
**101.LAB	Inline XBRL Taxonomy Extension Label Linkbase Document
**101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase Document
**101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase Document
104	Cover Page Interactive Data File (contained in Exhibit 101)

*

Filed herewith

**

Pursuant to Rule 406T of Regulation S-T, the Interactive Data Files on Exhibit 101 hereto are deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for purposes of Section 18 of the Securities and Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections.

57

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		CRESTWOOD EQUITY PARTNERS LP
		By:	CRESTWOOD EQUITY GP LLC
			(its general partner)
Date:	November 3, 2022	By:	/s/ JOHN BLACK
			John Black
			Executive Vice President and Chief Financial Officer
			(Duly Authorized Officer and Principal Financial Officer)
		CRESTWOOD MIDSTREAM PARTNERS LP
		By:	CRESTWOOD MIDSTREAM GP LLC
			(its general partner)
Date:	November 3, 2022	By:	/s/ JOHN BLACK
			John Black
			Executive Vice President and Chief Financial Officer
			(Duly Authorized Officer and Principal Financial Officer)

58

EX-31.1

Exhibit 31.1

CERTIFICATIONS

I, Robert G. Phillips, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Crestwood Equity Partners LP (the “registrant”);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d - 15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: November 3, 2022

/s/ Robert G. Phillips

Robert G. Phillips

Founder, Chairman and Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATIONS

I, John Black, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Crestwood Equity Partners LP (the “registrant”);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d - 15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: November 3, 2022

/s/ John Black

John Black

Executive Vice President and Chief Financial Officer

EX-31.3

Exhibit 31.3

CERTIFICATIONS

I, Robert G. Phillips, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Crestwood Midstream Partners LP (the “registrant”);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d - 15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: November 3, 2022

/s/ Robert G. Phillips

Robert G. Phillips

Founder, Chairman and Chief Executive Officer

EX-31.4

Exhibit 31.4

CERTIFICATIONS

I, John Black, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Crestwood Midstream Partners LP (the “registrant”);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d - 15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: November 3, 2022

/s/ John Black

John Black

Executive Vice President and Chief Financial Officer

EX-32.1

Exhibit 32.1

Certification of the Chief Executive Officer

Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Crestwood Equity Partners LP (the “Company”) on Form 10-Q for the period ended September 30, 2022, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert G. Phillips, Chief Executive Officer of Crestwood Equity Partners LP, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

	/s/ Robert G. Phillips
November 3, 2022	Robert G. Phillips Chief Executive Officer

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

Certification of the Chief Financial Officer

Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Crestwood Equity Partners LP (the “Company”) on Form 10-Q for the period ended September 30, 2022, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, John Black, Chief Financial Officer of Crestwood Equity Partners LP, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

	/s/ John Black
November 3, 2022	John Black Chief Financial Officer

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.3

Exhibit 32.3

Certification of the Chief Executive Officer

Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Crestwood Midstream Partners LP (the “Company”) on Form 10-Q for the period ended September 30, 2022, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert G. Phillips, Chief Executive Officer of Crestwood Midstream Partners LP, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

	/s/ Robert G. Phillips
November 3, 2022	Robert G. Phillips Chief Executive Officer

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.4

Exhibit 32.4

Certification of the Chief Financial Officer

Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Crestwood Midstream Partners LP (the “Company”) on Form 10-Q for the period ended September 30, 2022, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, John Black, Chief Financial Officer of Crestwood Midstream Partners LP, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

	/s/ John Black
November 3, 2022	John Black Chief Financial Officer

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Cover Page - shares	9 Months Ended
	Sep. 30, 2022	Oct. 28, 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	Q3
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		104,652,379
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	Sep. 30, 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	Q3
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	Sep. 30, 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

XML

Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Assets
Cash	$ 6.4	$ 13.3
Accounts receivable, less allowance for doubtful accounts of $0.6 million at both September 30, 2022 and December 31, 2021	479.8	378.0
Inventory	159.1	156.5
Assets from price risk management activities	112.7	42.1
Assets held for sale, net	205.7	0.0
Prepaid expenses and other current assets	9.2	14.8
Total current assets	972.9	604.7
Property, plant and equipment	5,141.4	3,771.5
Less: accumulated depreciation	752.1	992.1
Property, plant and equipment, net	4,389.3	2,779.4
Intangible assets	1,420.2	1,126.1
Less: accumulated amortization	285.1	393.2
Intangible assets, net	1,135.1	732.9
Goodwill	251.3	138.6
Operating lease right-of-use assets, net	18.6	27.4
Investments in unconsolidated affiliates	121.4	155.8
Other non-current assets	10.8	6.9
Total assets	6,899.4	4,445.7
Current liabilities:
Accounts payable	386.2	336.5
Accrued expenses and other liabilities	204.5	147.1
Liabilities from price risk management activities	36.9	114.6
Current portion of long-term debt	0.0	0.2
Total current liabilities	627.6	598.4
Long-term debt, less current portion	3,570.0	2,052.1
Other long-term liabilities	325.7	258.7
Deferred income taxes	3.5	2.3
Total liabilities	4,526.8	2,911.5
Commitments and contingencies (Note 9)
Interest of non-controlling partner in subsidiary	434.4	434.6
Partners’ capital:
Crestwood Equity Partners LP partners’ capital (104,651,317 and 62,991,511 common units issued and outstanding at September 30, 2022 and December 31, 2021)	1,326.2	487.6
Preferred units (71,257,445 units issued and outstanding at both September 30, 2022 and December 31, 2021)	612.0	612.0
Total partners’ capital	1,938.2	1,099.6
Total liabilities and capital	$ 6,899.4	$ 4,445.7
Limited Partners' Capital Account, Units Issued	104,651,317	62,991,511
Limited Partners' Capital Account, Units Outstanding	104,651,317	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	$ 5.8	$ 12.9
Accounts receivable, less allowance for doubtful accounts of $0.6 million at both September 30, 2022 and December 31, 2021	479.8	378.0
Inventory	159.1	156.5
Assets from price risk management activities	112.7	42.1
Assets held for sale, net	205.7	0.0
Prepaid expenses and other current assets	9.2	14.4
Total current assets	972.3	603.9
Property, plant and equipment	5,138.2	4,100.8
Less: accumulated depreciation	752.0	1,193.0
Property, plant and equipment, net	4,386.2	2,907.8
Intangible assets	1,420.2	1,126.1
Less: accumulated amortization	285.1	393.2
Intangible assets, net	1,135.1	732.9
Goodwill	251.3	138.6
Operating lease right-of-use assets, net	18.6	27.4
Investments in unconsolidated affiliates	121.4	155.8
Other non-current assets	8.7	4.8
Total assets	6,893.6	4,571.2
Current liabilities:
Accounts payable	386.1	336.4
Accrued expenses and other liabilities	203.3	146.1
Liabilities from price risk management activities	36.9	114.6
Current portion of long-term debt	0.0	0.2
Total current liabilities	626.3	597.3
Long-term debt, less current portion	3,570.0	2,052.1
Other long-term liabilities	323.6	254.1
Deferred income taxes	2.2	0.8
Total liabilities	4,522.1	2,904.3
Commitments and contingencies (Note 9)
Interest of non-controlling partner in subsidiary	434.4	434.6
Partners’ capital:
Partners' capital	1,937.1	1,232.3
Total liabilities and capital	$ 6,893.6	$ 4,571.2

XML

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Allowance for doubtful accounts	$ 0.6	$ 0.6
Limited Partners' Capital Account, Units Issued	104,651,317	62,991,511
Limited Partners' Capital Account, Units Outstanding	104,651,317	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	$ 0.6	$ 0.6

XML

Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Revenues:
Revenues	$ 1,566.0	$ 1,226.3	$ 4,597.8	$ 3,188.6
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 15)	51.3	34.8	232.9	101.3
Total costs of product/services sold	1,286.8	1,099.3	3,864.4	2,710.3
Operating expenses and other:
Operations and maintenance	55.0	31.6	144.0	90.2
General and administrative	33.9	25.9	103.8	67.4
Depreciation, amortization and accretion	86.9	64.6	242.3	182.6
Loss on long-lived assets, net	175.9	18.5	186.9	19.6
Gain Loss on Acquisition	(75.3)	0.0	(75.3)	0.0
Total expenses	276.4	140.6	601.7	359.8
Operating income (loss)	2.8	(13.6)	131.7	118.5
Earnings (loss) from unconsolidated affiliates, net	3.2	4.9	12.2	(125.9)
Interest and debt expense, net	(47.6)	(30.9)	(123.8)	(102.0)
Gain (Loss) on Extinguishment of Debt	0.0	0.0	0.0	(6.7)
Other income, net	0.0	0.1	0.2	0.2
Loss before income taxes	(41.6)	(39.5)	20.3	(115.9)
Provision for income taxes	(1.4)	(0.1)	(1.7)	(0.1)
Net income (loss)	(43.0)	(39.6)	18.6	(116.0)
Net income attributable to non-controlling partner	10.3	10.3	30.8	30.7
Net income (loss) attributable to parent	(53.3)	(49.9)	(12.2)	(146.7)
Net income attributable to preferred unit holders	15.0	15.0	45.0	45.0
Net loss attributable to partners	$ (68.3)	$ (64.9)	$ (57.2)	$ (191.7)
Net loss per limited partner unit: (Note 12)
Basic (in dollars per share)	$ (0.64)	$ (1.03)	$ (0.59)	$ (2.88)
Diluted (in dollars per share)	$ (0.64)	$ (1.03)	$ (0.59)	$ (2.88)
Weighted-average limited partners’ units outstanding:
Basic (units)	107.1	62.9	97.1	66.6
Diluted (units)	107.1	62.9	97.1	66.6
Affiliated Entity
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 15)	$ 51.3	$ 34.8	$ 232.9	$ 101.3
Crestwood Midstream Partners LP
Revenues:
Revenues	1,566.0	1,226.3	4,597.8	3,188.6
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 15)	51.3	34.8	232.9	101.3
Total costs of product/services sold	1,286.8	1,099.3	3,864.4	2,710.3
Operating expenses and other:
Operations and maintenance	55.0	31.6	144.0	90.2
General and administrative	32.3	24.4	99.0	61.3
Depreciation, amortization and accretion	86.8	68.2	248.0	193.2
Loss on long-lived assets, net	247.6	18.5	311.9	19.6
Gain Loss on Acquisition	(75.3)	0.0	(75.3)	0.0
Total expenses	346.4	142.7	727.6	364.3
Operating income (loss)	(67.2)	(15.7)	5.8	114.0
Earnings (loss) from unconsolidated affiliates, net	3.2	4.9	12.2	(125.9)
Interest and debt expense, net	(47.6)	(30.9)	(123.8)	(102.0)
Gain (Loss) on Extinguishment of Debt	0.0	0.0	0.0	(6.7)
Loss before income taxes	(111.6)	(41.7)	(105.8)	(120.6)
Provision for income taxes	(1.4)	(0.1)	(1.6)	(0.1)
Net income (loss)	(113.0)	(41.8)	(107.4)	(120.7)
Net income attributable to non-controlling partner	10.3	10.3	30.8	30.7
Net income (loss) attributable to parent	(123.3)	(52.1)	(138.2)	(151.4)
Product
Revenues:
Revenues	1,332.8	1,120.8	3,938.3	2,872.1
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	1,228.6	1,060.2	3,613.4	2,595.8
Product | Crestwood Midstream Partners LP
Revenues:
Revenues	1,332.8	1,120.8	3,938.3	2,872.1
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	1,228.6	1,060.2	3,613.4	2,595.8
Service
Revenues:
Revenues	92.4	98.4	286.8	291.3
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	6.9	4.3	18.1	13.2
Service | Crestwood Midstream Partners LP
Revenues:
Revenues	92.4	98.4	286.8	291.3
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	6.9	4.3	18.1	13.2
Product, Related Party
Revenues:
Revenues	83.2	6.5	222.7	24.2
Product, Related Party | Crestwood Midstream Partners LP
Revenues:
Revenues	83.2	6.5	222.7	24.2
Service, Related Party
Revenues:
Revenues	57.6	0.6	150.0	1.0
Service, Related Party | Crestwood Midstream Partners LP
Revenues:
Revenues	$ 57.6	$ 0.6	$ 150.0	$ 1.0

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Consolidated Statement of Partners' Capital - USD ($) $ in Millions	Total	Preferred Units	Common unit	Partners' Capital	Crestwood Midstream Partners LP	Crestwood Midstream Partners LP Partners' 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		$ 612.0	$ 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)
Retirement of common units (in units)								(11,500,000)	(400,000)
Distributions to partners		(15.0)	(46.4)	(61.4)		(334.0)
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		15.0	(63.4)	(48.4)		(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		612.0	655.6	1,267.6		1,414.7
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		612.0	1,043.4	1,655.4		1,805.1
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss) attributable to parent	$ (146.7)				$ (151.4)
Preferred units, ending balance (in units) at Sep. 30, 2021							71,300,000
Partner units, ending balance (in units) at Sep. 30, 2021								62,900,000	0
Ending Balance at Sep. 30, 2021		612.0	464.3	1,076.3		1,213.5
Preferred units, beginning balance (in units) at Mar. 31, 2021							71,300,000
Partner units, beginning balance (in units) at Mar. 31, 2021								62,800,000	0
Beginning balance at Mar. 31, 2021		612.0	655.6	1,267.6		1,414.7
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(15.0)	(39.3)	(54.3)		(61.4)
Unit-based compensation charges			7.6	7.6		7.6
Taxes paid for unit-based compensation vesting (in shares)								0
Taxes paid for unit-based compensation vesting			(0.1)	(0.1)		(0.1)
Other			(0.3)	(0.3)
Net income (loss) attributable to parent		15.0	(63.4)	(48.4)		(48.8)
Preferred units, ending balance (in units) at Jun. 30, 2021							71,300,000
Partner units, ending balance (in units) at Jun. 30, 2021								62,800,000	0
Ending Balance at Jun. 30, 2021		612.0	560.1	1,172.1		1,312.0
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(15.0)	(39.3)	(54.3)		(55.9)
Unit-based compensation charges (in shares)								100,000
Unit-based compensation charges			9.6	9.6		9.6
Taxes paid for unit-based compensation vesting			(0.1)	(0.1)		(0.1)
Other			(1.1)	(1.1)
Net income (loss) attributable to parent	$ (49.9)	15.0	(64.9)	(49.9)	(52.1)	(52.1)
Preferred units, ending balance (in units) at Sep. 30, 2021							71,300,000
Partner units, ending balance (in units) at Sep. 30, 2021								62,900,000	0
Ending Balance at Sep. 30, 2021		612.0	464.3	1,076.3		1,213.5
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								63,000,000.0
Beginning balance at Dec. 31, 2021		612.0	487.6	1,099.6	1,232.3	1,232.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(15.0)	(60.9)	(75.9)		(238.1)
Issuance of common units (in shares)										33,800,000
Issuance of common units (Note 3)			930.0	930.0
Non-cash contribution from partner (Note 11)						1,075.1
Cash contribution from partner (Note 11)						14.9
Unit-based compensation charges (in shares)								1,600,000
Unit-based compensation charges			13.0	13.0		13.0
Taxes paid for unit-based compensation vesting (in shares)								(500,000)
Taxes paid for unit-based compensation vesting			(14.9)	(14.9)		(14.9)
Other (in shares)	100,000
Other			2.2	2.2		0.1
Net income (loss) attributable to parent		15.0	(3.0)	12.0		10.0
Preferred units, ending balance (in units) at Mar. 31, 2022							71,300,000
Partner units, ending balance (in units) at Mar. 31, 2022								98,000,000.0
Ending Balance at Mar. 31, 2022		612.0	1,354.0	1,966.0		2,092.4
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								63,000,000.0
Beginning balance at Dec. 31, 2021		612.0	487.6	1,099.6	1,232.3	1,232.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss) attributable to parent	$ (12.2)				(138.2)
Preferred units, ending balance (in units) at Sep. 30, 2022	71,257,445						71,300,000
Partner units, ending balance (in units) at Sep. 30, 2022								104,700,000
Ending Balance at Sep. 30, 2022		612.0	1,326.2	1,938.2	1,937.1	1,937.1
Preferred units, beginning balance (in units) at Mar. 31, 2022							71,300,000
Partner units, beginning balance (in units) at Mar. 31, 2022								98,000,000.0
Beginning balance at Mar. 31, 2022		612.0	1,354.0	1,966.0		2,092.4
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(15.0)	(64.2)	(79.2)		(81.6)
Unit-based compensation charges			8.6	8.6		8.6
Taxes paid for unit-based compensation vesting			(0.7)	(0.7)		(0.7)
Other			(0.4)	(0.4)
Net income (loss) attributable to parent		15.0	14.1	29.1		(24.9)
Preferred units, ending balance (in units) at Jun. 30, 2022							71,300,000
Partner units, ending balance (in units) at Jun. 30, 2022								98,000,000.0
Ending Balance at Jun. 30, 2022		612.0	1,311.4	1,923.4		1,993.8
Increase (Decrease) in Partners' Capital [Roll Forward]
Retirement of common units (in units)								(4,600,000)
Distributions to partners		(15.0)	(71.6)	(86.6)		(217.9)
Issuance of common units (in shares)										11,300,000
Issuance of common units (Note 3)			270.8	270.8
Purchase of common units (Note 11)			(123.7)	(123.7)
Non-cash contribution from partner (Note 11)						127.3
Cash contribution from partner (Note 11)						149.4
Unit-based compensation charges			8.0	8.0		8.0
Taxes paid for unit-based compensation vesting			(0.2)	(0.2)		(0.2)
Other			(0.2)	(0.2)
Net income (loss) attributable to parent	$ (53.3)	15.0	(68.3)	(53.3)	(123.3)	(123.3)
Preferred units, ending balance (in units) at Sep. 30, 2022	71,257,445						71,300,000
Partner units, ending balance (in units) at Sep. 30, 2022								104,700,000
Ending Balance at Sep. 30, 2022		$ 612.0	$ 1,326.2	$ 1,938.2	$ 1,937.1	$ 1,937.1

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Consolidated Statements of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Operating activities
Net income (loss)	$ 18.6	$ (116.0)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	242.3	182.6
Amortization of debt-related deferred costs and fair value adjustment	1.7	5.1
Unit-based compensation charges	26.8	22.8
Loss on long-lived assets, net	186.9	19.6
Gain Loss on Acquisition	(75.3)	0.0
Loss on modification/extinguishment of debt	0.0	6.7
(Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received	(0.9)	137.5
Deferred income taxes	1.1	(0.4)
Other	0.0	0.2
Changes in operating assets and liabilities	(123.9)	114.8
Net cash provided by operating activities	277.3	372.9
Investing activities
Acquisition, net of cash acquired (Note 3)	(604.3)	0.0
Purchases of property, plant and equipment	(147.3)	(55.8)
Investments in unconsolidated affiliates	(90.2)	(10.2)
Capital distributions from unconsolidated affiliates	9.4	648.4
Net proceeds from sale of assets	315.2	0.5
Net cash provided by (used in) investing activities	(517.2)	582.9
Financing activities
Proceeds from the issuance of long-term debt	3,072.0	2,236.4
Payments on long-term debt	(2,393.1)	(2,695.9)
Payments on finance leases	(31.3)	(2.1)
Payments for deferred financing costs	(1.8)	(11.1)
Net proceeds from issuance of non-controlling interest	0.0	1.0
Payments for Repurchase of Common Stock and Other	0.0	(275.6)
Payments for Crestwood Holdings Transactions	(123.7)	0.0
Distributions to partners	(196.7)	(125.0)
Distributions to non-controlling partner	(31.0)	(29.9)
Distributions to preferred unitholders	(45.0)	(45.0)
Taxes paid for unit-based compensation vesting	(15.8)	(8.3)
Other	(0.6)	0.0
Net cash provided by (used in) financing activities	233.0	(955.5)
Net change in cash	(6.9)	0.3
Cash at beginning of period	13.3	14.0
Cash at end of period	6.4	14.3
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	19.9	(9.2)
Crestwood Midstream Partners LP
Operating activities
Net income (loss)	(107.4)	(120.7)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	248.0	193.2
Amortization of debt-related deferred costs and fair value adjustment	1.7	5.1
Unit-based compensation charges	26.8	22.8
Loss on long-lived assets, net	311.9	19.6
Gain Loss on Acquisition	(75.3)	0.0
Loss on modification/extinguishment of debt	0.0	6.7
(Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received	(0.9)	137.5
Deferred income taxes	1.2	0.0
Other	0.0	0.2
Changes in operating assets and liabilities	(123.9)	114.1
Net cash provided by operating activities	282.1	378.5
Investing activities
Acquisition, net of cash acquired (Note 3)	(602.7)	0.0
Purchases of property, plant and equipment	(146.6)	(55.8)
Investments in unconsolidated affiliates	(90.2)	(10.2)
Capital distributions from unconsolidated affiliates	9.4	648.4
Net proceeds from sale of assets	315.2	0.5
Net cash provided by (used in) investing activities	(514.9)	582.9
Financing activities
Proceeds from the issuance of long-term debt	3,072.0	2,236.4
Payments on long-term debt	(2,393.1)	(2,695.9)
Payments on finance leases	(31.3)	(2.1)
Payments for deferred financing costs	(1.8)	(11.1)
Net proceeds from issuance of non-controlling interest	0.0	1.0
Contributions from partner	164.3	0.0
Distributions to partners	(537.6)	(451.3)
Distributions to non-controlling partner	(31.0)	(29.9)
Taxes paid for unit-based compensation vesting	(15.8)	(8.3)
Net cash provided by (used in) financing activities	225.7	(961.2)
Net change in cash	(7.1)	0.2
Cash at beginning of period	12.9	13.7
Cash at end of period	5.8	13.9
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$ 19.9	(9.2)
Non-Controlling Partners
Financing activities
Net proceeds from issuance of non-controlling interest		$ 1.0

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Organization and Business Description

9 Months Ended

Sep. 30, 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 September 30, 2022 and for the three and nine months ended September 30, 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, as the context requires.

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.

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Basis of Presentation and Summary of Significant Accounting Policies

9 Months Ended

Sep. 30, 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.

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Acquisitions and Divestitures

9 Months Ended

Sep. 30, 2022

Business Combination and Asset Acquisition [Abstract]

Acquisitions and Divestitures

Acquisitions and Divestitures

Acquisitions

During the nine months ended September 30, 2022, we completed several acquisitions which are further described below. We accounted for each of these acquisitions as business combinations using the acquisition method of accounting. In addition, the purchase accounting for each of these acquisitions reflects the adoption of Accounting Standards Update (ASU) 2021-08, Business Combinations (Topic 805) during the nine months ended September 30, 2022.

Oasis Merger

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 Oasis 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.

The fair value of the assets acquired and liabilities assumed were determined 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%. Certain 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 following table summarizes the final valuation of the assets acquired and liabilities assumed at the acquisition date (in millions):

Cash	$	14.9
Other current assets	63.2
Property, plant and equipment	1,264.4
Intangible assets	464.0
Total assets acquired	1,806.5
Current liabilities	48.2
Long-term debt(1)	698.7
Other long-term liabilities(2)	25.8
Total liabilities assumed	772.7
Net assets acquired excluding goodwill	1,033.8
Goodwill	56.2
Net assets acquired	$	1,090.0

(1)    Consists of approximately $218 million outstanding borrowings under the Oasis Midstream credit facility, which was immediately repaid upon the closing of the Oasis 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 Oasis Merger, see Note 8.

(2)    Consists primarily of liabilities for asset retirement obligations of approximately $16.1 million.

The identifiable intangible assets primarily consist of customer relationships 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. We reflected approximately $48.8 million of goodwill in our gathering and processing north segment and approximately $7.4 million in our gathering and processing south segment.

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 nine months ended September 30, 2022, we recognized approximately $20.1 million of transaction costs related to the Oasis Merger, which are included in general and administrative expenses in our consolidated statements of operations. During the three and nine months ended September 30, 2022, we recognized approximately $110.8 million and $275.1 million of revenues and $37.7 million and $94.0 million of net income related to Oasis Midstream’s operations.

Sendero Acquisition

On July 11, 2022, we acquired Sendero Midstream Partners, LP (Sendero), a privately-held midstream company, for cash consideration of approximately $631.2 million (Sendero Acquisition). Sendero’s assets are located in Eddy County, New Mexico and its operations include natural gas gathering, compression and processing services.

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. 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 13%. The preliminary fair values of property, plant and equipment, intangible assets and liabilities and goodwill 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 the Sendero Acquisition in 2022.

The following table summarizes the preliminary fair values of the assets acquired and liabilities assumed at the acquisition date (in millions):

Cash	$	28.5
Other current assets	77.9
Property, plant and equipment	440.2
Intangible assets	138.9
Other non-current assets	0.2
Total assets acquired	685.7
Current liabilities	64.1
Long-term liabilities(1)	17.8
Total liabilities assumed	81.9
Net assets acquired excluding goodwill	603.8
Goodwill	27.4
Total purchase price	$	631.2

(1)    Includes intangible liabilities of approximately $14.0 million which are further described below.

The identifiable intangible assets primarily consist of customer relationships with a weighted-average remaining life of 20 years and the identifiable intangible liabilities primarily consist of revenue contracts with a remaining life of eight years. The goodwill recognized relates primarily to the anticipated operating synergies between the assets acquired and our existing operations.

The financial results of Sendero are included in our gathering and processing south segment from the date of acquisition. During the three and nine months ended September 30, 2022, we recognized approximately $8.4 million and $9.3 million of transaction costs related to the Sendero Acquisition, which are included in general and administrative expenses in our consolidated statements of operations. During both the three and nine months ended September 30, 2022, we recognized approximately $159.0 million of revenues and $18.1 million of net income related to Sendero’s operations.

CPJV Acquisition

On July 11, 2022, we acquired First Reserve Management, L.P.’s (First Reserve) 50% equity interest in Crestwood Permian Basin Holdings LLC (Crestwood Permian) in exchange for approximately $5.9 million in cash and approximately 11.3 million newly issued CEQP common units (CPJV Acquisition). Prior to the CPJV Acquisition, we owned a 50% equity interest in Crestwood Permian, which we accounted for under the equity method of accounting. As a result of this transaction, we control and own 100% of the equity interests in Crestwood Permian.

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. 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 15%. The preliminary fair values of property, plant and equipment, intangible assets and liabilities, goodwill and an investment in an unconsolidated affiliate 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 the CPJV Acquisition in 2022.

The following table summarizes the preliminary fair values of the assets acquired and liabilities assumed at the acquisition date (in millions):

Cash	$	149.4
Other current assets	83.3
Property, plant and equipment	453.4
Intangible assets	16.5
Investment in unconsolidated affiliate	78.6
Goodwill	29.1
Other non-current assets	4.9
Total assets acquired	815.2
Current liabilities	80.4
Long-term debt	140.2
Other long-term liabilities(1)	47.9
Total liabilities assumed	268.5
Estimated fair value of 100% of interest in Crestwood Permian	546.7
Less:
Elimination of equity interest in Crestwood Permian	194.7
Gain on acquisition of Crestwood Permian	75.3
Total purchase price	$	276.7

(1)    Includes intangible liabilities of approximately $38.9 million which are further described below.

The identifiable intangible assets primarily consist of customer relationships with a weighted-average remaining life of 20 years and the identifiable intangible liabilities primarily consist of revenue contracts with a remaining life of 10 years. The goodwill recognized relates primarily to the anticipated operating synergies between the assets acquired and our existing operations. As shown in the table above, the fair value of the assets acquired and liabilities assumed in the CPJV Acquisition exceeded the sum of the cash consideration paid, the fair value of the common units issued and the historical book value of our 50% equity interest in Crestwood Permian (which was remeasured at fair value and derecognized) and, as a result, we recognized a gain of approximately $75.3 million, which is included in gain on acquisition in our consolidated statements of operations.

The consolidated financial results of Crestwood Permian are included in our gathering and processing south segment from the date of acquisition. During the three and nine months ended September 30, 2022, we recognized approximately $0.1 million and $0.3 million of transaction costs related to the CPJV Acquisition, which are included in general and administrative expenses in our consolidated statements of operations. During both the three and nine months ended September 30, 2022, we recognized approximately $157.0 million of revenues and $8.4 million of net income related to Crestwood Permian’s operations.

The tables below present selected unaudited pro forma information as if the acquisitions described above 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 acquisitions had been completed as of the date indicated. The pro forma 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 and liabilities 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.

Our consolidated statements of operations for the three and nine months ended September 30, 2022 reflect the results of the Sendero and Crestwood Permian for the period from July 11, 2022 to September 30, 2022. The historical results for Sendero and Crestwood Permian for the period from July 1, 2022 to July 10, 2022 were not material and as a result, the tables below do not reflect selected unaudited pro forma information for the three months ended September 30, 2022.

Crestwood Equity

	Three Months Ended September 30,		Nine Months Ended September 30,
	2021		2022		2021
Revenues	$	1,398.3	$	4,832.0	$	3,626.1
Net income (loss)	$	(23.6)	$	45.1	$	(65.1)
Net loss per limited partner unit:
Basic and Diluted	$	(0.45)	$	(0.28)	$	(1.26)

Crestwood Midstream

	Three Months Ended September 30,		Nine Months Ended September 30,
	2021		2022		2021
Revenues	$	1,398.3	$	4,832.0	$	3,626.1
Net loss	$	(25.8)	$	(156.2)	$	(69.8)

Divestitures

Barnett

On July 1, 2022, we sold our assets in the Barnett Shale to EnLink Midstream, LLC (EnLink) for approximately $290 million, including working capital adjustments. During the nine months ended September 30, 2022, Crestwood Midstream recorded a loss on the sale of approximately $53 million, which is included in loss on long-lived assets, net on its consolidated statement of operations. Crestwood Equity’s historical carrying value of the property, plant and equipment related to the Barnett Shale assets was less than the sales proceeds due to historical impairments previously recorded on the property, plant and equipment by Crestwood Equity and as a result, during the three months ended September 30, 2022, Crestwood Equity recorded a gain on the sale of approximately $72 million, which is included in gain (loss) on long-lived assets, net on its consolidated statement of operations. The sale of the Barnett assets resulted in a decrease of approximately $346.9 million and $221.9 million of property, plant and equipment, net at CMLP and CEQP, respectively, and a decrease of approximately $18.9 million in asset retirement obligations at both CMLP and CEQP. For a further description of our assets in the Barnett Shale, which were previously included in our gathering and processing south segment, see our 2021 Annual Report on Form 10-K.

Marcellus

On October 25, 2022, we sold our assets in the Marcellus Shale for approximately $206 million. As a result of the sale, we reflected these assets as current assets held for sale, net, on our consolidated balance sheets at September 30, 2022, and recorded a loss on long-lived assets of approximately $248.2 million during the three months ended September 30, 2022 for the difference between the historical carrying value of the net assets and liabilities to be sold and the proceeds received from the sale. The current assets held for sale, net, were recorded at fair value based on the sales proceeds, which is a Level 3 fair value measurement, and consist primarily of property, plant and equipment and intangible assets.

During the three months ended September 30, 2021, we recorded a loss on long-lived assets of approximately $19 million related to the abandonment and dismantlement of certain of our Marcellus West Union compressor station assets, which were located in West Virginia and provided compression and dehydration services to our customers. For a further description of our assets in the Marcellus Shale, which are included in our gathering and processing south segment, see our 2021 Annual Report on Form 10-K.

Other

During the nine months ended September 30, 2022, we recorded a loss on long-lived assets of approximately $7.0 million related to the anticipated sale of parts inventory related to our legacy Granite Wash operations.

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Certain Balance Sheet Information

9 Months Ended

Sep. 30, 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):

	September 30,		December 31,
	2022		2021
CMLP
Accrued expenses	$	71.9	$	66.3
Accrued property taxes	8.5		4.4
Income tax payable	0.7		0.4
Interest payable	56.6		30.6
Accrued additions to property, plant and equipment	42.6		17.4
Operating leases	8.2		13.2
Finance leases	2.2		1.7
Contract liabilities	12.2		10.7
Asset retirement obligations	0.4		1.4
Total CMLP accrued expenses and other liabilities	$	203.3	$	146.1
CEQP
Accrued expenses	1.1		0.9
Income tax payable	0.1		0.1
Total CEQP accrued expenses and other liabilities	$	204.5	$	147.1

Other Long-Term Liabilities

Other long-term liabilities consisted of the following (in millions):

	September 30,		December 31,
	2022		2021
CMLP
Contract liabilities	$	209.1	$	187.1
Intangible liabilities	51.7		—
Asset retirement obligations	33.9		34.8
Operating leases	14.5		19.4
Other	14.4		12.8
Total CMLP other long-term liabilities	$	323.6	$	254.1
CEQP
Other	2.1		4.6
Total CEQP other long-term liabilities	$	325.7	$	258.7

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Investments in Unconsolidated Affiliates

9 Months Ended

Sep. 30, 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 Unconsolidated Affiliates				Earnings (Loss) from Unconsolidated Affiliates
					Three Months Ended				Nine Months Ended
	September 30,		December 31,		September 30,				September 30,
	2022		2021		2022		2021		2022		2021
Crestwood Permian Basin Holdings LLC(1)	$	—	$	116.1	$	1.3	$	4.2	$	8.7	$	4.4
Crestwood Permian Basin LLC(2)	77.1		—		0.7		—		0.7		—
Tres Palacios Holdings LLC(3)	41.2		36.2		1.3		(0.1)		3.2		9.1
Powder River Basin Industrial Complex, LLC(4)	3.1		3.5		(0.1)		(0.1)		(0.4)		—
Stagecoach Gas Services LLC(5)	—		—		—		0.9		—		(139.4)
Total	$	121.4	$	155.8	$	3.2	$	4.9	$	12.2	$	(125.9)

(1)On July 11, 2022, we acquired the remaining 50% equity interest in Crestwood Permian and as a result, we control and own 100% of the equity interests in Crestwood Permian. As a result of this transaction, we eliminated our historical equity investment in Crestwood Permian of approximately $194.7 million as of July 11, 2022 and began consolidating Crestwood Permian’s operations. Our Crestwood Permian investment was previously included in our gathering and processing south segment. See Note 3 for a further discussion of this acquisition.

(2)As described above, on July 11, 2022, we acquired the remaining 50% equity interest in Crestwood Permian, which owns a 50% equity interest in Crestwood Permian Basin LLC (Crestwood Permian Basin). Shell Midstream Partners L.P., a subsidiary of Royal Dutch Shell plc, owns the remaining 50% equity interest in Crestwood Permian Basin. Crestwood Permian Basin owns the Nautilus natural gas gathering system and related assets, which are further described in our 2021 Annual Report on Form 10-K. As of September 30, 2022, our equity in the underlying net assets of Crestwood Permian Basin was less than our carrying value of our investment balance by approximately $2.3 million. During the three and nine months ended September 30, 2022, we recorded amortization of less than $0.1 million related to this basis difference, which is reflected as a decrease in our earnings from unconsolidated affiliates in our consolidated statements of operations. Our Crestwood Permian Basin investment is included in our gathering and processing south segment.

(3)As of September 30, 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 $20.6 million. During both the three and nine months ended September 30, 2022 and 2021, we recorded amortization of approximately $0.3 million and $0.9 million, respectively, 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.

(4)As of September 30, 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.

(5)In 2021, we and Con Edison Gas Pipeline and Storage Northeast, LLC each sold our 50% equity interest in our Stagecoach Gas Services LLC (Stagecoach Gas) equity investment to a subsidiary of Kinder Morgan, Inc. During the nine months ended September 30, 2021, we recorded a $155.4 million reduction in our equity earnings from unconsolidated affiliates related to losses recorded by us and our Stagecoach Gas equity investment associated with the sale, which also eliminated our $51.3 million historical basis difference between our investment balance and the equity in the underlying net assets of Stagecoach Gas. In addition, our earnings from unconsolidated affiliates during the nine months ended September 30, 2021, were also reduced by our proportionate share of transaction costs of approximately $3.0 million related to the sale, which were paid by us in July 2021 on behalf of Stagecoach Gas. 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
	Nine Months Ended				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
Crestwood Permian	$	13.6	$	8.9	$	83.5	$	3.3
Crestwood Permian Basin	2.2		—		—		—
Tres Holdings	4.9		13.1		6.7		6.9
PRBIC	—		0.1		—		—
Stagecoach Gas	—		640.9		—		—
Total	$	20.7	$	663.0	$	90.2	$	10.2

(1)    In October 2022, we received a cash distribution from Tres Holdings of approximately $3.9 million. In addition, in October 2022, we made cash contributions of approximately $0.4 million and $0.3 million to Tres Holdings and PRBIC, respectively. In July 2021, Stagecoach Gas closed on the sale of certain of its wholly-owned subsidiaries to a subsidiary of Kinder Morgan as described above and distributed to us approximately $613.9 million as our proportionate share of the gross proceeds received from the sale.

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Risk Management

9 Months Ended

Sep. 30, 2022

Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]

Risk Management

Risk Management

We are exposed to certain market risks related to our ongoing business operations. These risks include exposure to changing commodity prices. We utilize derivative instruments to manage our exposure to fluctuations in commodity prices, which is discussed below. Additional information related to our derivatives is discussed in Note 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				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
Product revenues	$	84.7	$	129.4	$	395.7	$	296.9
Gain (loss) reflected in product costs	$	45.0	$	(53.4)	$	(6.3)	$	(94.8)

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:

	September 30, 2022		December 31, 2021
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, ethane, butane, heating oil and crude oil (MMBbls)	66.1	69.8	71.6	75.8
Natural gas (Bcf)	38.0	43.2	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, 88% 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):

	September 30, 2022		December 31, 2021
Aggregate fair value liability of derivative instruments with credit-risk-related contingent features(1)	$	15.6	$	57.9
Broker-related net derivative asset (liability) position	$	(24.0)	$	104.8
Broker-related cash collateral posted (received)	$	57.4	$	(76.8)
Cash collateral received, net	$	29.7	$	11.4

(1)At September 30, 2022 and December 31, 2021, we posted $7.2 million and $1.5 million of collateral associated with these derivatives.

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Fair Value Measurements

9 Months Ended

Sep. 30, 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 September 30, 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 September 30, 2022 and December 31, 2021 (in millions):

	September 30, 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	$	36.7	$	656.3	$	—	$	693.0	$	(584.5)	$	4.2	$	112.7
Other investments(2)	2.4		—		—		2.4		—		—		2.4
Total assets at fair value	$	39.1	$	656.3	$	—	$	695.4	$	(584.5)	$	4.2	$	115.1
Liabilities
Liabilities from price risk management	$	49.7	$	595.2	$	—	$	644.9	$	(584.5)	$	(23.5)	$	36.9
Total liabilities at fair value	$	49.7	$	595.2	$	—	$	644.9	$	(584.5)	$	(23.5)	$	36.9
	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 September 30, 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 Facilities

The fair value of the amounts outstanding under our credit facilities approximates their respective carrying amounts as of September 30, 2022 and December 31, 2021, due primarily to the variable nature of the interest rates of the instruments, which is considered a Level 2 fair value measurement. See Note 8 for a further discussion of our credit facilities.

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):

	September 30, 2022				December 31, 2021
	Carrying  Amount		Fair Value		Carrying  Amount		Fair Value
2025 Senior Notes	$	497.3	$	473.5	$	496.5	$	511.9
2027 Senior Notes	$	595.1	$	545.6	$	594.2	$	615.0
February 2029 Senior Notes	$	691.8	$	627.2	$	690.8	$	727.3
April 2029 Senior Notes(1)	$	477.8	$	433.1	$	—	$	—

(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 is further described in Note 8.

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Long-Term Debt

9 Months Ended

Sep. 30, 2022

Debt Disclosure [Abstract]

Long-Term Debt

Long-Term Debt

Long-term debt consisted of the following (in millions):

	September 30, 2022		December 31, 2021
CMLP Credit Facility	$	1,102.6	$	282.0
CPBH Credit Facility	216.7		—
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	27.8		—
Other	—		0.2
Less: deferred financing costs, net	27.1		29.9
Total debt	3,570.0		2,052.3
Less: current portion	—		0.2
Total long-term debt, less current portion	$	3,570.0	$	2,052.1

Credit Facilities

CMLP 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. In addition, we borrowed approximately $631.2 million under the CMLP Credit Facility to fund the Sendero Acquisition. In October 2022, we amended the CMLP Credit Facility to increase the capacity of the facility from $1.5 billion to $1.75 billion under the terms of the credit agreement.

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 September 30, 2022, the net debt to consolidated EBITDA ratio was approximately 3.93 to 1.0, the consolidated EBITDA to consolidated interest expense ratio was approximately 5.11 to 1.0, and the senior secured leverage ratio was 1.29 to 1.0.

At September 30, 2022, Crestwood Midstream had $382.6 million of available capacity under its credit facility considering the most restrictive debt covenants in its credit agreement. At September 30, 2022 and December 31, 2021, Crestwood Midstream’s outstanding standby letters of credit were $14.8 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 4.70% and 7.25% at September 30, 2022 and 1.90% and 4.00% at December 31, 2021. The weighted-average interest rate on outstanding borrowings as of September 30, 2022 and December 31, 2021 was 4.97% and 1.91%.

CPBH Credit Facility. In conjunction with the CPJV Acquisition in July 2022, we assumed a credit agreement entered into by CPB Subsidiary Holdings LLC (CPB Holdings), a wholly-owned subsidiary of Crestwood Permian. The credit agreement allows for revolving loans, letters of credit and swing line loans of up to $230 million (the CPBH Credit Facility). The CPBH Credit Facility has an accordion feature that allows CPB Holdings to increase the available borrowings by up to an additional $85 million, subject to certain conditions. The CPBH Credit Facility matures in October 2025 and is secured by substantially all of the assets of Crestwood Permian.

Borrowings under the CPBH Credit Facility bear interest at either:

•the Alternate Base Rate, which is defined as the highest of (i) the federal funds rate plus 0.50%; (ii) Wells Fargo Bank’s prime rate; or (iii) the Adjusted Term SOFR (as defined in the credit agreement) for a one-month tenor plus 1% per annum; plus a margin varying from 1.50% to 2.50% depending on our most recent consolidated total leverage ratio; or

•the Adjusted Term SOFR plus a margin varying from 2.50% to 3.50% depending on our most recent consolidated total leverage ratio.

The unused portion of the CPBH Credit Facility is subject to a commitment fee ranging from 0.375% to 0.50% according to Crestwood Permian’s most recent consolidated total leverage ratio. Interest on the Alternate Base Rate loans is payable quarterly, or if the Adjusted Term SOFR applies, interest is payable at certain intervals selected by us.

At September 30, 2022, we had $13.3 million of available capacity under the CPBH Credit Facility considering the most restrictive covenants in the credit agreement. The interest rates on borrowings under the CPBH Credit Facility were between 5.20% and 7.75% at September 30, 2022. The weighted average interest rate on outstanding borrowings as of September 30, 2022 was 5.92%.

The CPBH Credit Facility contains various covenants and restrictive provisions that limit Crestwood Permian’s ability to, among other things, (i) incur additional debt; (ii) make distributions on or redeem or repurchase units; (iii) make certain investments and acquisitions; (iv) incur or permit certain liens to exist; (v) merge, consolidate or amalgamate with another company; and (vi) transfer or dispose of assets.

CPB Holdings is required under its credit agreement to maintain a net debt to consolidated EBITDA ratio (as defined in the credit agreement) of not more than 5.00 to 1.0, and a consolidated EBITDA to consolidated interest expense ratio (as defined in the credit agreement) of not less than 2.50 to 1.0. At September 30, 2022, the net debt to consolidated EBITDA ratio was approximately 3.21 to 1.0, and the consolidated EBITDA to consolidated interest expense ratio was approximately 13.19 to 1.0.

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 and nine months ended September 30, 2022, we recorded a reduction to our interest and debt expense of approximately $1.1 million and $2.9 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. During the nine months ended September 30, 2021, we redeemed $687.2 million of principal outstanding under our senior notes due in 2023. In conjunction with the repayment of the notes, we recognized a loss on extinguishment of debt of approximately $6.7 million during the nine months ended September 30, 2021, and paid approximately $8.6 million of accrued interest on our senior notes due in 2023 on the dates they were repurchased. During 2021, we repaid all amounts outstanding under our senior notes due 2023 and funded the repayment using a portion of the proceeds from the issuance of the February 2029 Senior Notes and borrowings under the CMLP Credit Facility.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2022

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Legal Proceedings

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 related to this matter (including approximately $3.2 million paid during the nine months ended September 30, 2022).

A jury trial concluded on June 17, 2022, and a final judgement was entered on October 24, 2022. The final judgment includes an award of damages of approximately $20.7 million, a pre-judgement interest award of approximately $17.7 million and attorney fees and other costs of approximately $4.7 million. We have insurance coverage related to certain pre-judgement interest awards but have not recorded a receivable related to any potential insurance recovery at September 30, 2022. We expect to appeal the final judgement and, as a result are unable to predict the ultimate 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 September 30, 2022 and December 31, 2021, we had approximately $29.8 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 September 30, 2022 and December 31, 2021, our accrual of approximately $4.2 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 $4.2 million to $5.2 million at September 30, 2022. Certain of our environmental-related matters are insurable events under our policies and at September 30, 2022, we recorded insurance receivables of approximately $3.7 million.

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
	September 30, 2022		December 31, 2021		September 30, 2022		December 31, 2021
Self-insurance reserves(1)	$	5.4	$	5.5	$	4.5	$	4.7

(1)At September 30, 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 September 30, 2022 and December 31, 2021, we have no amounts accrued for these indemnifications.

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Leases

9 Months Ended

Sep. 30, 2022

Leases [Abstract]

Leases

Leases

The following table summarizes the balance sheet information related to our operating and finance leases (in millions):

	September 30, 2022		December 31, 2021
Operating Leases
Operating lease right-of-use assets, net	$	18.6	$	27.4
Accrued expenses and other liabilities	$	8.2	$	13.2
Other long-term liabilities	14.5		19.4
Total operating lease liabilities	$	22.7	$	32.6
Finance Leases
Property, plant and equipment	$	14.6	$	12.3
Less: accumulated depreciation	9.5		9.2
Property, plant and equipment, net	$	5.1	$	3.1
Accrued expenses and other liabilities	$	2.2	$	1.7
Other long-term liabilities	2.7		1.2
Total finance lease liabilities	$	4.9	$	2.9

Lease expense. Our operating lease expense, net totaled $3.4 million and $3.7 million for the three months ended September 30, 2022 and 2021 and $9.2 million and $12.8 million for the nine months ended September 30, 2022 and 2021. Our finance lease expense totaled $0.9 million and $0.8 million for the three months ended September 30, 2022 and 2021 and $2.7 million and $2.6 million for the nine months ended September 30, 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 sold the crude oil railcars to a third party for approximately $24.7 million and we recognized a loss on the sale of approximately $4.1 million during the nine months ended September 30, 2022.

Lessee, Finance Leases

Leases

The following table summarizes the balance sheet information related to our operating and finance leases (in millions):

	September 30, 2022		December 31, 2021
Operating Leases
Operating lease right-of-use assets, net	$	18.6	$	27.4
Accrued expenses and other liabilities	$	8.2	$	13.2
Other long-term liabilities	14.5		19.4
Total operating lease liabilities	$	22.7	$	32.6
Finance Leases
Property, plant and equipment	$	14.6	$	12.3
Less: accumulated depreciation	9.5		9.2
Property, plant and equipment, net	$	5.1	$	3.1
Accrued expenses and other liabilities	$	2.2	$	1.7
Other long-term liabilities	2.7		1.2
Total finance lease liabilities	$	4.9	$	2.9

Lease expense. Our operating lease expense, net totaled $3.4 million and $3.7 million for the three months ended September 30, 2022 and 2021 and $9.2 million and $12.8 million for the nine months ended September 30, 2022 and 2021. Our finance lease expense totaled $0.9 million and $0.8 million for the three months ended September 30, 2022 and 2021 and $2.7 million and $2.6 million for the nine months ended September 30, 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 sold the crude oil railcars to a third party for approximately $24.7 million and we recognized a loss on the sale of approximately $4.1 million during the nine months ended September 30, 2022.

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Partners' Capital

9 Months Ended

Sep. 30, 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 and approximately 20.9 million newly issued CEQP common 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.

On July 11, 2022, we acquired First Reserve’s 50% equity interest in Crestwood Permian in exchange for approximately $5.9 million in cash and approximately 11.3 million newly issued CEQP common units. For a further discussion of the CPJV Acquisition, see Note 3.

On September 15, 2022, CEQP acquired 4.6 million CEQP common units from OMS Holdings LLC, a subsidiary of Chord Energy Corporation (formerly Oasis Petroleum), for approximately $123.7 million. This transaction resulted in CEQP retiring the common units acquired from OMS Holdings LLC.

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 (Crestwood Holdings Transactions). CEQP reflected the purchase price as a reduction to its common unitholders’ partners’ capital in its consolidated statement of partners’ capital during the first quarter of 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 $2.4 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 first quarter of 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 first quarter of 2021.

Distributions

Crestwood Equity

Limited Partners. A summary of CEQP’s limited partner quarterly cash distributions for the nine months ended September 30, 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
May 6, 2022	May 13, 2022	$	0.655	64.2
August 5, 2022	August 12, 2022	$	0.655	71.6
				$	196.7
2021
February 5, 2021	February 12, 2021	$	0.625	$	46.4
May 7, 2021	May 14, 2021	$	0.625	39.3
August 6, 2021	August 13, 2021	$	0.625	39.3
				$	125.0

On October 20, 2022, we declared a distribution of $0.655 per limited partner unit to be paid on November 14, 2022 to unitholders of record on November 7, 2022 with respect to the quarter ended September 30, 2022.

Preferred Unitholders. During the nine months ended September 30, 2022 and 2021, we paid cash distributions to our preferred unitholders of approximately $45 million in both periods. On October 20, 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 September 30, 2022.

Crestwood Midstream

During the nine months ended September 30, 2022 and 2021, Crestwood Midstream paid cash distributions of $537.6 million and $451.3 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.

On July 11, 2022, Crestwood Midstream received a non-cash contribution of approximately $127.3 million from Crestwood Equity related to the acquisition of its 50% equity interest in Crestwood Permian. In addition, on July 11, 2022, Crestwood Equity contributed cash acquired in conjunction with this acquisition of approximately $149.4 million to Crestwood Midstream.

For a further discussion of these acquisitions, see Note 3.

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 tables show the change in our non-controlling interest in subsidiary at September 30, 2022 and 2021 (in millions):

Balance at December 31, 2021	$	434.6
Distributions to non-controlling partner	(31.0)
Net income attributable to non-controlling partner	30.8
Balance at September 30, 2022	$	434.4

Balance at December 31, 2020	$	432.7
Contributions from non-controlling partner	1.0
Distributions to non-controlling partner	(29.9)
Net income attributable to non-controlling partner	30.7
Balance at September 30, 2021	$	434.5

In October 2022, Crestwood Niobrara paid cash distributions to Jackalope Holdings of approximately $10.3 million with respect to the quarter ended September 30, 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 September 30, 2022, we had total unamortized compensation expense of approximately $3.8 million related to these performance units. During the three and nine months ended September 30, 2022, we recognized compensation expense of $0.4 million and $1.1 million related to these performance units, which is included in general and administrative expenses on our consolidated statements of operations.

During the nine months ended September 30, 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 nine months ended September 30, 2022 related to those performance units.

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Earnings Per Limited Partner Unit

9 Months Ended

Sep. 30, 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 and nine months ended September 30, 2022 and 2021 (in millions):

	Three Months Ended		Nine Months Ended
	September 30,		September 30,
	2022	2021	2022	2021
Preferred units(1)	7.1	7.1	7.1	7.1
Crestwood Niobrara’s preferred units(1)	3.9	3.9	3.9	3.9
Unit-based compensation performance units(1)	0.1	0.2	0.2	0.1
Subordinated units(2)	—	—	—	0.1

(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 its subordinated units. For additional information regarding the retirement of the subordinated units, see Note 11.

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Segments

9 Months Ended

Sep. 30, 2022

Segment Reporting [Abstract]

Segments

Segments

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 Crestwood Permian, Sendero, Oasis Midstream Delaware and Marcellus operations and our Crestwood Permian Basin 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). On July 1, 2022, we sold our Barnett assets which were previously included in our gathering and processing south segment. On July 11, 2022, we acquired Sendero and we reflect its results in our gathering and processing south segment. Also, on July 11, 2022, we acquired First Reserve’s 50% interest in Crestwood Permian, and as a result, we own and control 100% of the equity interests in Crestwood Permian and we reflect its consolidated results in our gathering and processing south segment. Prior to July 11, 2022, our 50% equity method investment in Crestwood Permian was also reflected in our gathering and processing south segment. For a further discussion of these acquisitions and divestiture, see Note 3.

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 gathering, compression, treating and processing services, crude oil gathering and storage services and produced water gathering 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 services and produced water gathering and disposal services to producers in the Delaware and Marcellus 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 income (loss) to EBITDA (in millions):

	CEQP								CMLP
	Three Months Ended				Nine Months Ended				Three Months Ended				Nine Months Ended
	September 30,				September 30,				September 30,				September 30,
	2022		2021		2022		2021		2022		2021		2022		2021
Net income (loss)	$	(43.0)	$	(39.6)	$	18.6	$	(116.0)	$	(113.0)	$	(41.8)	$	(107.4)	$	(120.7)
Add:
Interest and debt expense, net	47.6		30.9		123.8		102.0		47.6		30.9		123.8		102.0
Loss on modification/extinguishment of debt	—		—		—		6.7		—		—		—		6.7
Provision for income taxes	1.4		0.1		1.7		0.1		1.4		0.1		1.6		0.1
Depreciation, amortization and accretion	86.9		64.6		242.3		182.6		86.8		68.2		248.0		193.2
EBITDA	$	92.9	$	56.0	$	386.4	$	175.4	$	22.8	$	57.4	$	266.0	$	181.3

The following tables summarize CEQP’s and CMLP’s reportable segment data for the three and nine months ended September 30, 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 $2.5 million and $4.9 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 September 30, 2022 and 2021 and $12.0 million and $182.4 million for the nine months ended September 30, 2022 and 2021.

Segment EBITDA Information

	Three Months Ended September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	272.6	$	177.4	$	1,116.0	$	—	$	1,566.0
Intersegment revenues, net	142.2		137.8		(280.0)		—		—
Costs of product/services sold	230.2		249.6		807.0		—		1,286.8
Operations and maintenance expense	27.4		14.3		13.3		—		55.0
General and administrative expense	—		—		—		32.3		32.3
Loss on long-lived assets, net	—		(247.6)		—		—		(247.6)
Gain on acquisition	—		75.3		—		—		75.3
Earnings from unconsolidated affiliates, net	—		2.0		1.2		—		3.2
Crestwood Midstream EBITDA	$	157.2	$	(119.0)	$	16.9	$	(32.3)	$	22.8
Crestwood Equity
General and administrative expense	—		—		—		1.6		1.6
Gain on long-lived assets	—		71.7		—		—		71.7
Crestwood Equity EBITDA	$	157.2	$	(47.3)	$	16.9	$	(33.9)	$	92.9

	Three Months Ended September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	144.5	$	26.7	$	1,055.1	$	—	$	1,226.3
Intersegment revenues, net	125.6		—		(125.6)		—		—
Costs of product/services sold	149.7		0.4		949.2		—		1,099.3
Operations and maintenance expense	14.1		5.4		12.1		—		31.6
General and administrative expense	—		—		—		24.4		24.4
Gain (loss) on long-lived assets, net	0.1		(18.6)		—		—		(18.5)
Earnings from unconsolidated affiliates, net	—		4.2		0.7		—		4.9
Crestwood Midstream EBITDA	$	106.4	$	6.5	$	(31.1)	$	(24.4)	$	57.4
Crestwood Equity
General and administrative expense	—		—		—		1.5		1.5
Other income, net	—		—		—		0.1		0.1
Crestwood Equity EBITDA	$	106.4	$	6.5	$	(31.1)	$	(25.8)	$	56.0

	Nine Months Ended September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	787.2	$	243.4	$	3,567.2	$	—	$	4,597.8
Intersegment revenues, net	421.2		137.8		(559.0)		—		—
Costs of product/services sold	686.6		249.6		2,928.2		—		3,864.4
Operations and maintenance expense	78.6		28.6		36.8		—		144.0
General and administrative expense	—		—		—		99.0		99.0
Loss on long-lived assets, net	—		(307.8)		(4.1)		—		(311.9)
Gain on acquisition	—		75.3		—		—		75.3
Earnings from unconsolidated affiliates, net	—		9.4		2.8		—		12.2
Crestwood Midstream EBITDA	$	443.2	$	(120.1)	$	41.9	$	(99.0)	$	266.0
Crestwood Equity
General and administrative expense	—		—		—		4.8		4.8
Gain on long-lived assets(1)	—		125.0		—		—		125.0
Other income, net	—		—		—		0.2		0.2
Crestwood Equity EBITDA	$	443.2	$	4.9	$	41.9	$	(103.6)	$	386.4

(1)Represents the elimination of the loss on long-lived assets of approximately $53 million recorded by CMLP related to the sale of our assets in the Barnett Shale and the gain on long-lived assets of approximately $72 million recorded by CEQP related to this sale. For a further discussion of this transaction, see Note 3.

	Nine Months Ended September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	422.9	$	76.0	$	2,689.7	$	—	$	3,188.6
Intersegment revenues, net	315.1		—		(315.1)		—		—
Costs of product/services sold	386.4		0.8		2,323.1		—		2,710.3
Operations and maintenance expense	38.2		17.4		34.6		—		90.2
General and administrative expense	—		—		—		61.3		61.3
Gain (loss) on long-lived assets, net	0.2		(19.9)		0.1		—		(19.6)
Earnings (loss) from unconsolidated affiliates, net	—		4.4		(130.3)		—		(125.9)
Crestwood Midstream EBITDA	$	313.6	$	42.3	$	(113.3)	$	(61.3)	$	181.3
Crestwood Equity
General and administrative expense	—		—		—		6.1		6.1
Other income, net	—		—		—		0.2		0.2
Crestwood Equity EBITDA	$	313.6	$	42.3	$	(113.3)	$	(67.2)	$	175.4

Other Segment Information

	CEQP				CMLP
	September 30, 2022		December 31, 2021		September 30, 2022		December 31, 2021
Total Assets
Gathering and Processing North	$	4,072.4	$	2,408.0	$	4,072.4	$	2,408.0
Gathering and Processing South	1,666.4		886.5		1,666.4		1,017.4
Storage and Logistics	1,131.1		1,125.1		1,131.1		1,125.1
Corporate	29.5		26.1		23.7		20.7
Total Assets	$	6,899.4	$	4,445.7	$	6,893.6	$	4,571.2

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Revenues

9 Months Ended

Sep. 30, 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 ASU 2014-09, Revenue from Contracts with Customers (Topic 606) totaled $456.4 million and $331.0 million at September 30, 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):

	September 30, 2022		December 31, 2021
Contract assets (non-current)(1)	$	5.6	$	1.3
Contract liabilities (current)(2)	$	12.2	$	10.7
Contract liabilities (non-current)(2)	$	209.1	$	187.1

(1)Includes approximately $4.7 million acquired in conjunction with the CPJV Acquisition.

(2)During the three and nine months ended September 30, 2022, we recognized revenues of approximately $4.0 million and $11.2 million that were previously included in contract liabilities at December 31, 2021. The remaining change in our contract liabilities during the three and nine months ended September 30, 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 September 30, 2022 (in millions):

Remainder of 2022	$	23.3
2023	70.4
2024	45.8
2025	2.3
2026	0.5
Thereafter	1.3
Total	$	143.6

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 and nine months ended September 30, 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 September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	33.4	$	10.1	$	—	$	—	$	43.5
Crude oil	14.7		1.7		—		—		16.4
Water	41.8		7.5		—		—		49.3
Processing
Natural gas	20.7		4.8		—		—		25.5
Compression
Natural gas	—		4.7		—		—		4.7
Storage
Crude oil	0.6		—		0.1		—		0.7
NGLs	—		—		2.2		—		2.2
Pipeline
Crude oil	—		—		0.6		—		0.6
NGLs	—		5.2		0.1		(5.2)		0.1
Transportation
Crude oil	1.5		0.1		—		—		1.6
NGLs	—		—		5.0		—		5.0
Product Sales
Natural gas	109.6		144.4		248.4		(205.6)		296.8
Crude oil	120.9		—		362.8		(9.8)		473.9
NGLs	68.3		136.2		411.7		(58.9)		557.3
Water	2.1		—		—		—		2.1
Other	0.8		—		0.2		(0.5)		0.5
Total Topic 606 revenues	414.4		314.7		1,031.1		(280.0)		1,480.2
Non-Topic 606 revenues	0.4		0.5		84.9		—		85.8
Total revenues	$	414.8	$	315.2	$	1,116.0	$	(280.0)	$	1,566.0

	Three Months Ended September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	13.7	$	21.6	$	—	$	—	$	35.3
Crude oil	17.1		—		—		—		17.1
Water	24.8		—		—		—		24.8
Processing
Natural gas	5.8		1.4		—		—		7.2
Compression
Natural gas	—		3.7		—		—		3.7
Storage
Crude oil	0.1		—		0.1		(0.1)		0.1
NGLs	—		—		2.6		—		2.6
Pipeline
Crude oil	—		—		0.6		—		0.6
Transportation
Crude oil	0.8		—		—		(0.1)		0.7
NGLs	—		—		4.1		—		4.1
Rail Loading
Crude oil	—		—		1.2		—		1.2
Product Sales
Natural gas	42.9		—		84.5		(42.7)		84.7
Crude oil	105.4		—		331.3		(25.1)		411.6
NGLs	59.1		—		500.1		(57.6)		501.6
Other	—		—		0.5		—		0.5
Total Topic 606 revenues	269.7		26.7		925.0		(125.6)		1,095.8
Non-Topic 606 revenues	0.4		—		130.1		—		130.5
Total revenues	$	270.1	$	26.7	$	1,055.1	$	(125.6)	$	1,226.3

	Nine Months Ended September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	92.2	$	57.0	$	—	$	—	$	149.2
Crude oil	43.6		4.6		—		—		48.2
Water	117.7		13.0		—		—		130.7
Processing
Natural gas	54.8		7.1		—		—		61.9
Compression
Natural gas	—		11.3		—		—		11.3
Storage
Crude oil	1.7		—		0.4		(0.2)		1.9
NGLs	—		—		6.9		—		6.9
Pipeline
Crude oil	—		—		1.5		—		1.5
NGLs	—		5.2		0.2		(5.2)		0.2
Transportation
Crude oil	4.2		0.5		—		(0.1)		4.6
NGLs	—		—		16.3		—		16.3
Rail Loading
Crude oil	—		—		0.4		—		0.4
Product Sales
Natural gas	269.1		145.3		508.0		(331.2)		591.2
Crude oil	394.9		—		1,130.3		(33.9)		1,491.3
NGLs	222.7		136.2		1,505.6		(187.9)		1,676.6
Water	5.0		—		—		—		5.0
Other	1.4		—		0.5		(0.5)		1.4
Total Topic 606 revenues	1,207.3		380.2		3,170.1		(559.0)		4,198.6
Non-Topic 606 revenues	1.1		1.0		397.1		—		399.2
Total revenues	$	1,208.4	$	381.2	$	3,567.2	$	(559.0)	$	4,597.8

	Nine Months Ended September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	40.5	$	59.5	$	—	$	—	$	100.0
Crude oil	56.2		—		—		—		56.2
Water	69.5		—		—		—		69.5
Processing
Natural gas	17.7		3.8		—		—		21.5
Compression
Natural gas	—		12.1		—		—		12.1
Storage
Crude oil	0.3		—		0.4		(0.3)		0.4
NGLs	—		—		8.7		—		8.7
Pipeline
Crude oil	—		—		2.0		—		2.0
NGLs	—		—		0.1		—		0.1
Transportation
Crude oil	1.9		—		—		(0.1)		1.8
NGLs	—		—		12.5		—		12.5
Rail Loading
Crude oil	—		—		3.4		—		3.4
Product Sales
Natural gas	111.9		0.6		224.4		(111.7)		225.2
Crude oil	297.1		—		926.9		(62.5)		1,161.5
NGLs	142.3		—		1,210.9		(140.5)		1,212.7
Other	—		—		1.4		—		1.4
Total Topic 606 revenues	737.4		76.0		2,390.7		(315.1)		2,889.0
Non-Topic 606 revenues	0.6		—		299.0		—		299.6
Total revenues	$	738.0	$	76.0	$	2,689.7	$	(315.1)	$	3,188.6

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Related Party Transactions

9 Months Ended

Sep. 30, 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.

On July 11, 2022, we acquired First Reserve’s 50% equity interest in Crestwood Permian. As a result of this transaction, we control and own 100% of the equity interests of Crestwood Permian and include their results in our consolidated financial statements. Prior to July 11, 2022, we owned a 50% equity interest in Crestwood Permian, which we accounted for under the equity method of accounting, and reflected transactions with Crestwood Permian as transactions with affiliates in the tables below.

As discussed above, in conjunction with our acquisition of First Reserve’s 50% equity interest in Crestwood Permian, we issued 11.3 million newly issued CEQP common units to First Reserve and as a result, First Reserve is considered a related party of CEQP and CMLP. In September 2022, we acquired 4.6 million CEQP common units from a subsidiary of Chord Energy Corporation and as result of this transaction, Chord Energy Corporation is no longer considered a related party of CEQP and CMLP.

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 nine months ended September 30, 2021, we paid approximately $0.6 million of capital expenditures to Applied Consultants, Inc., an affiliate of Crestwood Holdings. In addition, during the nine months ended September 30, 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 nine months ended September 30, 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				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
Revenues at CEQP and CMLP(1)	$	140.8	$	7.1	$	372.7	$	25.2
Costs of product/services sold at CEQP and CMLP(2)	$	51.3	$	34.8	$	232.9	$	101.3
Operations and maintenance expenses at CEQP and CMLP charged to our unconsolidated affiliates(3)	$	2.6	$	5.1	$	12.4	$	16.8
General and administrative expenses charged by CEQP to CMLP, net(4)	$	8.5	$	11.9	$	23.5	$	24.4
General and administrative expenses at CEQP and CMLP(5)	$	—	$	—	$	1.3	$	—

(1)Includes (i) $83.0 million and $218.9 million during the three and nine months ended September 30, 2022 primarily related to the sale of crude oil and NGLs to a subsidiary of Chord Energy Corporation (formerly Oasis Petroleum Inc.); (ii) $57.4 million and $148.6 million during the three and nine months ended September 30, 2022 primarily related to gathering and processing services under agreements with a subsidiary of Chord Energy Corporation (formerly Oasis Petroleum Inc.); (iii) $0.3 million and $3.9 million during the three and nine months ended September 30, 2022 and $7.1 million and $25.2 million during the three and nine months ended September 30, 2021 related to the sale of NGLs to a subsidiary of Crestwood Permian; and (iv) $0.1 million and $1.3 million during the three and nine months ended September 30, 2022 related to compressor leases with a subsidiary of Crestwood Permian;

(2)Includes (i) $41.5 million and $114.1 million during the three and nine months ended September 30, 2022 primarily related to purchases of NGLs from a subsidiary of Chord Energy Corporation (formerly Oasis Petroleum, Inc.); (ii) $9.2 million and $116.8 million during the three and nine months ended September 30, 2022 and $30.4 million and $75.5 million during the three and nine months ended September 30, 2021 related to purchases of natural gas and NGLs from a subsidiary of Crestwood Permian; (iii) $0.3 million and $1.7 million during the three and nine months ended September 30, 2022 and $0.2 million and $11.3 million during the three and nine months ended September 30, 2021 primarily related to purchases of natural gas from a subsidiary of Tres Holdings; (iv) $0.3 million during both the three and nine months ended September 31, 2022 related to gathering services under agreements Crestwood Permian Basin; and (v) $4.2 million and $14.5 million during the three and nine months ended September 30, 2021 related to purchases of NGLs from Ascent Resources - Utica, LLC, an affiliate of Crestwood Holdings.

(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 and nine months ended September 30, 2022, we charged $1.2 million and $3.5 million to Tres Holdings, $1.0 million to Crestwood Permian Basin in both periods and $0.4 million and $7.9 million to Crestwood Permian. During the three and nine months ended September 30, 2021, we charged $0.1 million and $3.4 million to Stagecoach Gas, $1.2 million and $3.6 million to Tres Holdings and $3.8 million and $9.8 million to Crestwood Permian.

(4)Includes $9.6 million and $26.8 million of unit-based compensation charges allocated from CEQP to CMLP during the three and nine months ended September 30, 2022 and $12.9 million and $27.4 million for the three and nine months ended September 30, 2021. In addition, includes $1.1 million and $3.3 million of CMLP’s general and administrative costs allocated to CEQP during the three and nine months ended September 30, 2022 and $1.0 million and $3.0 million for the three and nine months ended September 30, 2021.

(5)Represents general and administrative expenses related to a transition services agreement with Chord Energy Corporation (formerly Oasis Petroleum Inc.).

The following table shows balances with our affiliates which are reflected in our consolidated balance sheets (in millions):

	September 30, 2022		December 31, 2021
Accounts receivable at CEQP and CMLP	$	1.6	$	8.2
Accounts payable at CEQP and CMLP	$	2.2	$	12.0

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Basis of Presentation and Summary of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 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.

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Acquisitions and Divestitures (Tables)

9 Months Ended

Sep. 30, 2022

Business Combination and Asset Acquisition [Abstract]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed

The following table summarizes the final valuation of the assets acquired and liabilities assumed at the acquisition date (in millions):

Cash	$	14.9
Other current assets	63.2
Property, plant and equipment	1,264.4
Intangible assets	464.0
Total assets acquired	1,806.5
Current liabilities	48.2
Long-term debt(1)	698.7
Other long-term liabilities(2)	25.8
Total liabilities assumed	772.7
Net assets acquired excluding goodwill	1,033.8
Goodwill	56.2
Net assets acquired	$	1,090.0

(1)    Consists of approximately $218 million outstanding borrowings under the Oasis Midstream credit facility, which was immediately repaid upon the closing of the Oasis 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 Oasis Merger, see Note 8.

(2)    Consists primarily of liabilities for asset retirement obligations of approximately $16.1 million.

The following table summarizes the preliminary fair values of the assets acquired and liabilities assumed at the acquisition date (in millions):

Cash	$	28.5
Other current assets	77.9
Property, plant and equipment	440.2
Intangible assets	138.9
Other non-current assets	0.2
Total assets acquired	685.7
Current liabilities	64.1
Long-term liabilities(1)	17.8
Total liabilities assumed	81.9
Net assets acquired excluding goodwill	603.8
Goodwill	27.4
Total purchase price	$	631.2

(1)    Includes intangible liabilities of approximately $14.0 million which are further described below.

The following table summarizes the preliminary fair values of the assets acquired and liabilities assumed at the acquisition date (in millions):

Cash	$	149.4
Other current assets	83.3
Property, plant and equipment	453.4
Intangible assets	16.5
Investment in unconsolidated affiliate	78.6
Goodwill	29.1
Other non-current assets	4.9
Total assets acquired	815.2
Current liabilities	80.4
Long-term debt	140.2
Other long-term liabilities(1)	47.9
Total liabilities assumed	268.5
Estimated fair value of 100% of interest in Crestwood Permian	546.7
Less:
Elimination of equity interest in Crestwood Permian	194.7
Gain on acquisition of Crestwood Permian	75.3
Total purchase price	$	276.7

(1)    Includes intangible liabilities of approximately $38.9 million which are further described below.

Business Acquisition, Pro Forma Information

Crestwood Equity

	Three Months Ended September 30,		Nine Months Ended September 30,
	2021		2022		2021
Revenues	$	1,398.3	$	4,832.0	$	3,626.1
Net income (loss)	$	(23.6)	$	45.1	$	(65.1)
Net loss per limited partner unit:
Basic and Diluted	$	(0.45)	$	(0.28)	$	(1.26)

Crestwood Midstream

	Three Months Ended September 30,		Nine Months Ended September 30,
	2021		2022		2021
Revenues	$	1,398.3	$	4,832.0	$	3,626.1
Net loss	$	(25.8)	$	(156.2)	$	(69.8)

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Certain Balance Sheet Information (Tables)

9 Months Ended

Sep. 30, 2022

Balance Sheet Related Disclosures [Abstract]

Schedule of Accrued Liabilities

Accrued expenses and other liabilities consisted of the following (in millions):

	September 30,		December 31,
	2022		2021
CMLP
Accrued expenses	$	71.9	$	66.3
Accrued property taxes	8.5		4.4
Income tax payable	0.7		0.4
Interest payable	56.6		30.6
Accrued additions to property, plant and equipment	42.6		17.4
Operating leases	8.2		13.2
Finance leases	2.2		1.7
Contract liabilities	12.2		10.7
Asset retirement obligations	0.4		1.4
Total CMLP accrued expenses and other liabilities	$	203.3	$	146.1
CEQP
Accrued expenses	1.1		0.9
Income tax payable	0.1		0.1
Total CEQP accrued expenses and other liabilities	$	204.5	$	147.1

Schedule of Other Long-Term Liabilities

Other long-term liabilities consisted of the following (in millions):

	September 30,		December 31,
	2022		2021
CMLP
Contract liabilities	$	209.1	$	187.1
Intangible liabilities	51.7		—
Asset retirement obligations	33.9		34.8
Operating leases	14.5		19.4
Other	14.4		12.8
Total CMLP other long-term liabilities	$	323.6	$	254.1
CEQP
Other	2.1		4.6
Total CEQP other long-term liabilities	$	325.7	$	258.7

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Investments in Unconsolidated Affiliates (Tables)

9 Months Ended

Sep. 30, 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 Unconsolidated Affiliates				Earnings (Loss) from Unconsolidated Affiliates
					Three Months Ended				Nine Months Ended
	September 30,		December 31,		September 30,				September 30,
	2022		2021		2022		2021		2022		2021
Crestwood Permian Basin Holdings LLC(1)	$	—	$	116.1	$	1.3	$	4.2	$	8.7	$	4.4
Crestwood Permian Basin LLC(2)	77.1		—		0.7		—		0.7		—
Tres Palacios Holdings LLC(3)	41.2		36.2		1.3		(0.1)		3.2		9.1
Powder River Basin Industrial Complex, LLC(4)	3.1		3.5		(0.1)		(0.1)		(0.4)		—
Stagecoach Gas Services LLC(5)	—		—		—		0.9		—		(139.4)
Total	$	121.4	$	155.8	$	3.2	$	4.9	$	12.2	$	(125.9)

(1)On July 11, 2022, we acquired the remaining 50% equity interest in Crestwood Permian and as a result, we control and own 100% of the equity interests in Crestwood Permian. As a result of this transaction, we eliminated our historical equity investment in Crestwood Permian of approximately $194.7 million as of July 11, 2022 and began consolidating Crestwood Permian’s operations. Our Crestwood Permian investment was previously included in our gathering and processing south segment. See Note 3 for a further discussion of this acquisition.

(2)As described above, on July 11, 2022, we acquired the remaining 50% equity interest in Crestwood Permian, which owns a 50% equity interest in Crestwood Permian Basin LLC (Crestwood Permian Basin). Shell Midstream Partners L.P., a subsidiary of Royal Dutch Shell plc, owns the remaining 50% equity interest in Crestwood Permian Basin. Crestwood Permian Basin owns the Nautilus natural gas gathering system and related assets, which are further described in our 2021 Annual Report on Form 10-K. As of September 30, 2022, our equity in the underlying net assets of Crestwood Permian Basin was less than our carrying value of our investment balance by approximately $2.3 million. During the three and nine months ended September 30, 2022, we recorded amortization of less than $0.1 million related to this basis difference, which is reflected as a decrease in our earnings from unconsolidated affiliates in our consolidated statements of operations. Our Crestwood Permian Basin investment is included in our gathering and processing south segment.

(3)As of September 30, 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 $20.6 million. During both the three and nine months ended September 30, 2022 and 2021, we recorded amortization of approximately $0.3 million and $0.9 million, respectively, 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.

(4)As of September 30, 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.

(5)In 2021, we and Con Edison Gas Pipeline and Storage Northeast, LLC each sold our 50% equity interest in our Stagecoach Gas Services LLC (Stagecoach Gas) equity investment to a subsidiary of Kinder Morgan, Inc. During the nine months ended September 30, 2021, we recorded a $155.4 million reduction in our equity earnings from unconsolidated affiliates related to losses recorded by us and our Stagecoach Gas equity investment associated with the sale, which also eliminated our $51.3 million historical basis difference between our investment balance and the equity in the underlying net assets of Stagecoach Gas. In addition, our earnings from unconsolidated affiliates during the nine months ended September 30, 2021, were also reduced by our proportionate share of transaction costs of approximately $3.0 million related to the sale, which were paid by us in July 2021 on behalf of Stagecoach Gas. 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
	Nine Months Ended				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
Crestwood Permian	$	13.6	$	8.9	$	83.5	$	3.3
Crestwood Permian Basin	2.2		—		—		—
Tres Holdings	4.9		13.1		6.7		6.9
PRBIC	—		0.1		—		—
Stagecoach Gas	—		640.9		—		—
Total	$	20.7	$	663.0	$	90.2	$	10.2

(1)    In October 2022, we received a cash distribution from Tres Holdings of approximately $3.9 million. In addition, in October 2022, we made cash contributions of approximately $0.4 million and $0.3 million to Tres Holdings and PRBIC, respectively. In July 2021, Stagecoach Gas closed on the sale of certain of its wholly-owned subsidiaries to a subsidiary of Kinder Morgan as described above and distributed to us approximately $613.9 million as our proportionate share of the gross proceeds received from the sale.

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Risk Management (Tables)

9 Months Ended

Sep. 30, 2022

Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]

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				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
Product revenues	$	84.7	$	129.4	$	395.7	$	296.9
Gain (loss) reflected in product costs	$	45.0	$	(53.4)	$	(6.3)	$	(94.8)

Notional Amounts And Terms Of Company's Derivative Financial Instruments

The notional amounts of our derivative financial instruments include the following:

	September 30, 2022		December 31, 2021
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, ethane, butane, heating oil and crude oil (MMBbls)	66.1	69.8	71.6	75.8
Natural gas (Bcf)	38.0	43.2	31.9	43.4

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):

	September 30, 2022		December 31, 2021
Aggregate fair value liability of derivative instruments with credit-risk-related contingent features(1)	$	15.6	$	57.9
Broker-related net derivative asset (liability) position	$	(24.0)	$	104.8
Broker-related cash collateral posted (received)	$	57.4	$	(76.8)
Cash collateral received, net	$	29.7	$	11.4

(1)At September 30, 2022 and December 31, 2021, we posted $7.2 million and $1.5 million of collateral associated with these derivatives.

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Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 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 September 30, 2022 and December 31, 2021 (in millions):

	September 30, 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	$	36.7	$	656.3	$	—	$	693.0	$	(584.5)	$	4.2	$	112.7
Other investments(2)	2.4		—		—		2.4		—		—		2.4
Total assets at fair value	$	39.1	$	656.3	$	—	$	695.4	$	(584.5)	$	4.2	$	115.1
Liabilities
Liabilities from price risk management	$	49.7	$	595.2	$	—	$	644.9	$	(584.5)	$	(23.5)	$	36.9
Total liabilities at fair value	$	49.7	$	595.2	$	—	$	644.9	$	(584.5)	$	(23.5)	$	36.9
	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):

	September 30, 2022				December 31, 2021
	Carrying  Amount		Fair Value		Carrying  Amount		Fair Value
2025 Senior Notes	$	497.3	$	473.5	$	496.5	$	511.9
2027 Senior Notes	$	595.1	$	545.6	$	594.2	$	615.0
February 2029 Senior Notes	$	691.8	$	627.2	$	690.8	$	727.3
April 2029 Senior Notes(1)	$	477.8	$	433.1	$	—	$	—

(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 is further described in Note 8.

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Long-Term Debt (Tables)

9 Months Ended

Sep. 30, 2022

Debt Disclosure [Abstract]

Components Of Long-Term Debt

Long-term debt consisted of the following (in millions):

	September 30, 2022		December 31, 2021
CMLP Credit Facility	$	1,102.6	$	282.0
CPBH Credit Facility	216.7		—
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	27.8		—
Other	—		0.2
Less: deferred financing costs, net	27.1		29.9
Total debt	3,570.0		2,052.3
Less: current portion	—		0.2
Total long-term debt, less current portion	$	3,570.0	$	2,052.1

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Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 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
	September 30, 2022		December 31, 2021		September 30, 2022		December 31, 2021
Self-insurance reserves(1)	$	5.4	$	5.5	$	4.5	$	4.7

(1)At September 30, 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.

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Leases (Tables)

9 Months Ended

Sep. 30, 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):

	September 30, 2022		December 31, 2021
Operating Leases
Operating lease right-of-use assets, net	$	18.6	$	27.4
Accrued expenses and other liabilities	$	8.2	$	13.2
Other long-term liabilities	14.5		19.4
Total operating lease liabilities	$	22.7	$	32.6
Finance Leases
Property, plant and equipment	$	14.6	$	12.3
Less: accumulated depreciation	9.5		9.2
Property, plant and equipment, net	$	5.1	$	3.1
Accrued expenses and other liabilities	$	2.2	$	1.7
Other long-term liabilities	2.7		1.2
Total finance lease liabilities	$	4.9	$	2.9

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Partners' Capital (Tables)

9 Months Ended

Sep. 30, 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 nine months ended September 30, 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
May 6, 2022	May 13, 2022	$	0.655	64.2
August 5, 2022	August 12, 2022	$	0.655	71.6
				$	196.7
2021
February 5, 2021	February 12, 2021	$	0.625	$	46.4
May 7, 2021	May 14, 2021	$	0.625	39.3
August 6, 2021	August 13, 2021	$	0.625	39.3
				$	125.0

Summary of Change in Non-Controlling Interest in Subsidiary

The following tables show the change in our non-controlling interest in subsidiary at September 30, 2022 and 2021 (in millions):

Balance at December 31, 2021	$	434.6
Distributions to non-controlling partner	(31.0)
Net income attributable to non-controlling partner	30.8
Balance at September 30, 2022	$	434.4

Balance at December 31, 2020	$	432.7
Contributions from non-controlling partner	1.0
Distributions to non-controlling partner	(29.9)
Net income attributable to non-controlling partner	30.7
Balance at September 30, 2021	$	434.5

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Earnings Per Limited Partner Unit (Tables)

9 Months Ended

Sep. 30, 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 and nine months ended September 30, 2022 and 2021 (in millions):

	Three Months Ended		Nine Months Ended
	September 30,		September 30,
	2022	2021	2022	2021
Preferred units(1)	7.1	7.1	7.1	7.1
Crestwood Niobrara’s preferred units(1)	3.9	3.9	3.9	3.9
Unit-based compensation performance units(1)	0.1	0.2	0.2	0.1
Subordinated units(2)	—	—	—	0.1

(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 its subordinated units. For additional information regarding the retirement of the subordinated units, see Note 11.

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Segments (Tables)

9 Months Ended

Sep. 30, 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 income (loss) to EBITDA (in millions):

	CEQP								CMLP
	Three Months Ended				Nine Months Ended				Three Months Ended				Nine Months Ended
	September 30,				September 30,				September 30,				September 30,
	2022		2021		2022		2021		2022		2021		2022		2021
Net income (loss)	$	(43.0)	$	(39.6)	$	18.6	$	(116.0)	$	(113.0)	$	(41.8)	$	(107.4)	$	(120.7)
Add:
Interest and debt expense, net	47.6		30.9		123.8		102.0		47.6		30.9		123.8		102.0
Loss on modification/extinguishment of debt	—		—		—		6.7		—		—		—		6.7
Provision for income taxes	1.4		0.1		1.7		0.1		1.4		0.1		1.6		0.1
Depreciation, amortization and accretion	86.9		64.6		242.3		182.6		86.8		68.2		248.0		193.2
EBITDA	$	92.9	$	56.0	$	386.4	$	175.4	$	22.8	$	57.4	$	266.0	$	181.3

Summary Of Segment Information

The following tables summarize CEQP’s and CMLP’s reportable segment data for the three and nine months ended September 30, 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 $2.5 million and $4.9 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 September 30, 2022 and 2021 and $12.0 million and $182.4 million for the nine months ended September 30, 2022 and 2021.

Segment EBITDA Information

	Three Months Ended September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	272.6	$	177.4	$	1,116.0	$	—	$	1,566.0
Intersegment revenues, net	142.2		137.8		(280.0)		—		—
Costs of product/services sold	230.2		249.6		807.0		—		1,286.8
Operations and maintenance expense	27.4		14.3		13.3		—		55.0
General and administrative expense	—		—		—		32.3		32.3
Loss on long-lived assets, net	—		(247.6)		—		—		(247.6)
Gain on acquisition	—		75.3		—		—		75.3
Earnings from unconsolidated affiliates, net	—		2.0		1.2		—		3.2
Crestwood Midstream EBITDA	$	157.2	$	(119.0)	$	16.9	$	(32.3)	$	22.8
Crestwood Equity
General and administrative expense	—		—		—		1.6		1.6
Gain on long-lived assets	—		71.7		—		—		71.7
Crestwood Equity EBITDA	$	157.2	$	(47.3)	$	16.9	$	(33.9)	$	92.9

	Three Months Ended September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	144.5	$	26.7	$	1,055.1	$	—	$	1,226.3
Intersegment revenues, net	125.6		—		(125.6)		—		—
Costs of product/services sold	149.7		0.4		949.2		—		1,099.3
Operations and maintenance expense	14.1		5.4		12.1		—		31.6
General and administrative expense	—		—		—		24.4		24.4
Gain (loss) on long-lived assets, net	0.1		(18.6)		—		—		(18.5)
Earnings from unconsolidated affiliates, net	—		4.2		0.7		—		4.9
Crestwood Midstream EBITDA	$	106.4	$	6.5	$	(31.1)	$	(24.4)	$	57.4
Crestwood Equity
General and administrative expense	—		—		—		1.5		1.5
Other income, net	—		—		—		0.1		0.1
Crestwood Equity EBITDA	$	106.4	$	6.5	$	(31.1)	$	(25.8)	$	56.0

	Nine Months Ended September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	787.2	$	243.4	$	3,567.2	$	—	$	4,597.8
Intersegment revenues, net	421.2		137.8		(559.0)		—		—
Costs of product/services sold	686.6		249.6		2,928.2		—		3,864.4
Operations and maintenance expense	78.6		28.6		36.8		—		144.0
General and administrative expense	—		—		—		99.0		99.0
Loss on long-lived assets, net	—		(307.8)		(4.1)		—		(311.9)
Gain on acquisition	—		75.3		—		—		75.3
Earnings from unconsolidated affiliates, net	—		9.4		2.8		—		12.2
Crestwood Midstream EBITDA	$	443.2	$	(120.1)	$	41.9	$	(99.0)	$	266.0
Crestwood Equity
General and administrative expense	—		—		—		4.8		4.8
Gain on long-lived assets(1)	—		125.0		—		—		125.0
Other income, net	—		—		—		0.2		0.2
Crestwood Equity EBITDA	$	443.2	$	4.9	$	41.9	$	(103.6)	$	386.4

(1)Represents the elimination of the loss on long-lived assets of approximately $53 million recorded by CMLP related to the sale of our assets in the Barnett Shale and the gain on long-lived assets of approximately $72 million recorded by CEQP related to this sale. For a further discussion of this transaction, see Note 3.

	Nine Months Ended September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	422.9	$	76.0	$	2,689.7	$	—	$	3,188.6
Intersegment revenues, net	315.1		—		(315.1)		—		—
Costs of product/services sold	386.4		0.8		2,323.1		—		2,710.3
Operations and maintenance expense	38.2		17.4		34.6		—		90.2
General and administrative expense	—		—		—		61.3		61.3
Gain (loss) on long-lived assets, net	0.2		(19.9)		0.1		—		(19.6)
Earnings (loss) from unconsolidated affiliates, net	—		4.4		(130.3)		—		(125.9)
Crestwood Midstream EBITDA	$	313.6	$	42.3	$	(113.3)	$	(61.3)	$	181.3
Crestwood Equity
General and administrative expense	—		—		—		6.1		6.1
Other income, net	—		—		—		0.2		0.2
Crestwood Equity EBITDA	$	313.6	$	42.3	$	(113.3)	$	(67.2)	$	175.4

Other Segment Information

	CEQP				CMLP
	September 30, 2022		December 31, 2021		September 30, 2022		December 31, 2021
Total Assets
Gathering and Processing North	$	4,072.4	$	2,408.0	$	4,072.4	$	2,408.0
Gathering and Processing South	1,666.4		886.5		1,666.4		1,017.4
Storage and Logistics	1,131.1		1,125.1		1,131.1		1,125.1
Corporate	29.5		26.1		23.7		20.7
Total Assets	$	6,899.4	$	4,445.7	$	6,893.6	$	4,571.2

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Revenue Recognition (Tables)

9 Months Ended

Sep. 30, 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):

	September 30, 2022		December 31, 2021
Contract assets (non-current)(1)	$	5.6	$	1.3
Contract liabilities (current)(2)	$	12.2	$	10.7
Contract liabilities (non-current)(2)	$	209.1	$	187.1

(1)Includes approximately $4.7 million acquired in conjunction with the CPJV Acquisition.

(2)During the three and nine months ended September 30, 2022, we recognized revenues of approximately $4.0 million and $11.2 million that were previously included in contract liabilities at December 31, 2021. The remaining change in our contract liabilities during the three and nine months ended September 30, 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 September 30, 2022 (in millions):

Remainder of 2022	$	23.3
2023	70.4
2024	45.8
2025	2.3
2026	0.5
Thereafter	1.3
Total	$	143.6

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 and nine months ended September 30, 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 September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	33.4	$	10.1	$	—	$	—	$	43.5
Crude oil	14.7		1.7		—		—		16.4
Water	41.8		7.5		—		—		49.3
Processing
Natural gas	20.7		4.8		—		—		25.5
Compression
Natural gas	—		4.7		—		—		4.7
Storage
Crude oil	0.6		—		0.1		—		0.7
NGLs	—		—		2.2		—		2.2
Pipeline
Crude oil	—		—		0.6		—		0.6
NGLs	—		5.2		0.1		(5.2)		0.1
Transportation
Crude oil	1.5		0.1		—		—		1.6
NGLs	—		—		5.0		—		5.0
Product Sales
Natural gas	109.6		144.4		248.4		(205.6)		296.8
Crude oil	120.9		—		362.8		(9.8)		473.9
NGLs	68.3		136.2		411.7		(58.9)		557.3
Water	2.1		—		—		—		2.1
Other	0.8		—		0.2		(0.5)		0.5
Total Topic 606 revenues	414.4		314.7		1,031.1		(280.0)		1,480.2
Non-Topic 606 revenues	0.4		0.5		84.9		—		85.8
Total revenues	$	414.8	$	315.2	$	1,116.0	$	(280.0)	$	1,566.0

	Three Months Ended September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	13.7	$	21.6	$	—	$	—	$	35.3
Crude oil	17.1		—		—		—		17.1
Water	24.8		—		—		—		24.8
Processing
Natural gas	5.8		1.4		—		—		7.2
Compression
Natural gas	—		3.7		—		—		3.7
Storage
Crude oil	0.1		—		0.1		(0.1)		0.1
NGLs	—		—		2.6		—		2.6
Pipeline
Crude oil	—		—		0.6		—		0.6
Transportation
Crude oil	0.8		—		—		(0.1)		0.7
NGLs	—		—		4.1		—		4.1
Rail Loading
Crude oil	—		—		1.2		—		1.2
Product Sales
Natural gas	42.9		—		84.5		(42.7)		84.7
Crude oil	105.4		—		331.3		(25.1)		411.6
NGLs	59.1		—		500.1		(57.6)		501.6
Other	—		—		0.5		—		0.5
Total Topic 606 revenues	269.7		26.7		925.0		(125.6)		1,095.8
Non-Topic 606 revenues	0.4		—		130.1		—		130.5
Total revenues	$	270.1	$	26.7	$	1,055.1	$	(125.6)	$	1,226.3

	Nine Months Ended September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	92.2	$	57.0	$	—	$	—	$	149.2
Crude oil	43.6		4.6		—		—		48.2
Water	117.7		13.0		—		—		130.7
Processing
Natural gas	54.8		7.1		—		—		61.9
Compression
Natural gas	—		11.3		—		—		11.3
Storage
Crude oil	1.7		—		0.4		(0.2)		1.9
NGLs	—		—		6.9		—		6.9
Pipeline
Crude oil	—		—		1.5		—		1.5
NGLs	—		5.2		0.2		(5.2)		0.2
Transportation
Crude oil	4.2		0.5		—		(0.1)		4.6
NGLs	—		—		16.3		—		16.3
Rail Loading
Crude oil	—		—		0.4		—		0.4
Product Sales
Natural gas	269.1		145.3		508.0		(331.2)		591.2
Crude oil	394.9		—		1,130.3		(33.9)		1,491.3
NGLs	222.7		136.2		1,505.6		(187.9)		1,676.6
Water	5.0		—		—		—		5.0
Other	1.4		—		0.5		(0.5)		1.4
Total Topic 606 revenues	1,207.3		380.2		3,170.1		(559.0)		4,198.6
Non-Topic 606 revenues	1.1		1.0		397.1		—		399.2
Total revenues	$	1,208.4	$	381.2	$	3,567.2	$	(559.0)	$	4,597.8

	Nine Months Ended September 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	40.5	$	59.5	$	—	$	—	$	100.0
Crude oil	56.2		—		—		—		56.2
Water	69.5		—		—		—		69.5
Processing
Natural gas	17.7		3.8		—		—		21.5
Compression
Natural gas	—		12.1		—		—		12.1
Storage
Crude oil	0.3		—		0.4		(0.3)		0.4
NGLs	—		—		8.7		—		8.7
Pipeline
Crude oil	—		—		2.0		—		2.0
NGLs	—		—		0.1		—		0.1
Transportation
Crude oil	1.9		—		—		(0.1)		1.8
NGLs	—		—		12.5		—		12.5
Rail Loading
Crude oil	—		—		3.4		—		3.4
Product Sales
Natural gas	111.9		0.6		224.4		(111.7)		225.2
Crude oil	297.1		—		926.9		(62.5)		1,161.5
NGLs	142.3		—		1,210.9		(140.5)		1,212.7
Other	—		—		1.4		—		1.4
Total Topic 606 revenues	737.4		76.0		2,390.7		(315.1)		2,889.0
Non-Topic 606 revenues	0.6		—		299.0		—		299.6
Total revenues	$	738.0	$	76.0	$	2,689.7	$	(315.1)	$	3,188.6

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Related Party Transactions (Tables)

9 Months Ended

Sep. 30, 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				Nine Months Ended
	September 30,				September 30,
	2022		2021		2022		2021
Revenues at CEQP and CMLP(1)	$	140.8	$	7.1	$	372.7	$	25.2
Costs of product/services sold at CEQP and CMLP(2)	$	51.3	$	34.8	$	232.9	$	101.3
Operations and maintenance expenses at CEQP and CMLP charged to our unconsolidated affiliates(3)	$	2.6	$	5.1	$	12.4	$	16.8
General and administrative expenses charged by CEQP to CMLP, net(4)	$	8.5	$	11.9	$	23.5	$	24.4
General and administrative expenses at CEQP and CMLP(5)	$	—	$	—	$	1.3	$	—

(1)Includes (i) $83.0 million and $218.9 million during the three and nine months ended September 30, 2022 primarily related to the sale of crude oil and NGLs to a subsidiary of Chord Energy Corporation (formerly Oasis Petroleum Inc.); (ii) $57.4 million and $148.6 million during the three and nine months ended September 30, 2022 primarily related to gathering and processing services under agreements with a subsidiary of Chord Energy Corporation (formerly Oasis Petroleum Inc.); (iii) $0.3 million and $3.9 million during the three and nine months ended September 30, 2022 and $7.1 million and $25.2 million during the three and nine months ended September 30, 2021 related to the sale of NGLs to a subsidiary of Crestwood Permian; and (iv) $0.1 million and $1.3 million during the three and nine months ended September 30, 2022 related to compressor leases with a subsidiary of Crestwood Permian;

(2)Includes (i) $41.5 million and $114.1 million during the three and nine months ended September 30, 2022 primarily related to purchases of NGLs from a subsidiary of Chord Energy Corporation (formerly Oasis Petroleum, Inc.); (ii) $9.2 million and $116.8 million during the three and nine months ended September 30, 2022 and $30.4 million and $75.5 million during the three and nine months ended September 30, 2021 related to purchases of natural gas and NGLs from a subsidiary of Crestwood Permian; (iii) $0.3 million and $1.7 million during the three and nine months ended September 30, 2022 and $0.2 million and $11.3 million during the three and nine months ended September 30, 2021 primarily related to purchases of natural gas from a subsidiary of Tres Holdings; (iv) $0.3 million during both the three and nine months ended September 31, 2022 related to gathering services under agreements Crestwood Permian Basin; and (v) $4.2 million and $14.5 million during the three and nine months ended September 30, 2021 related to purchases of NGLs from Ascent Resources - Utica, LLC, an affiliate of Crestwood Holdings.

(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 and nine months ended September 30, 2022, we charged $1.2 million and $3.5 million to Tres Holdings, $1.0 million to Crestwood Permian Basin in both periods and $0.4 million and $7.9 million to Crestwood Permian. During the three and nine months ended September 30, 2021, we charged $0.1 million and $3.4 million to Stagecoach Gas, $1.2 million and $3.6 million to Tres Holdings and $3.8 million and $9.8 million to Crestwood Permian.

(4)Includes $9.6 million and $26.8 million of unit-based compensation charges allocated from CEQP to CMLP during the three and nine months ended September 30, 2022 and $12.9 million and $27.4 million for the three and nine months ended September 30, 2021. In addition, includes $1.1 million and $3.3 million of CMLP’s general and administrative costs allocated to CEQP during the three and nine months ended September 30, 2022 and $1.0 million and $3.0 million for the three and nine months ended September 30, 2021.

(5)Represents general and administrative expenses related to a transition services agreement with Chord Energy Corporation (formerly Oasis Petroleum Inc.).

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):

	September 30, 2022		December 31, 2021
Accounts receivable at CEQP and CMLP	$	1.6	$	8.2
Accounts payable at CEQP and CMLP	$	2.2	$	12.0

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Organization and Business Description (Details) - Crestwood Midstream Partners LP	9 Months Ended
	Sep. 30, 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%

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Acquisitions and Divestitures (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions				3 Months Ended		9 Months Ended
	Jul. 11, 2022	Jul. 01, 2022	Feb. 01, 2022	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Jul. 10, 2022	Apr. 30, 2022	Feb. 28, 2022	Dec. 31, 2021
Business Acquisition [Line Items]
Investments in unconsolidated affiliates				$ 121.4		$ 121.4					$ 155.8
Goodwill				251.3		251.3					138.6
Gain on acquisition				75.3	$ 0.0	75.3	$ 0.0
Revenues				1,566.0	1,226.3	4,597.8	3,188.6
Net income (loss)				(43.0)	(39.6)	18.6	(116.0)
Business Acquisition, Pro Forma Information
Revenues				1,398.3		4,832.0	3,626.1
Net income (loss)				$ (23.6)		$ 45.1	$ (65.1)
Diluted (in dollars per share)				$ (0.45)		$ (0.28)	$ (1.26)
Basic (in dollars per share)				$ (0.45)		$ (0.28)	$ (1.26)
Crestwood Permian Basin Holdings LLC
Business Acquisition [Line Items]
Investments in unconsolidated affiliates	$ 194.7			$ 0.0		$ 0.0					116.1
Business Acquisition, Pro Forma Information
Ownership percentage	50.00%							50.00%
Disposal Group, Disposed of by Sale, Not Discontinued Operations
Business Acquisition, Pro Forma Information
Disposal Group, Including Discontinued Operation, Consideration									$ 24.7
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal						4.1
Gathering and Processing South | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Marcellus
Business Acquisition, Pro Forma Information
Gain (Loss) on Sale of Assets and Asset Impairment Charges					19.0
Gathering and Processing South | Barnett Shale Assets | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Business Acquisition, Pro Forma Information
Disposal Group, Including Discontinued Operation, Consideration		$ 290.0
Gathering and Processing South | Granite Wash | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Business Acquisition, Pro Forma Information
Gain (Loss) on Sale of Assets and Asset Impairment Charges						7.0
Gathering and Processing South | Marcellus Shale Assets | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Business Acquisition, Pro Forma Information
Disposal Group, Including Discontinued Operation, Consideration		206.0
April 2029 Senior Notes
Business Acquisition, Pro Forma Information
Debt Instrument, Fair Value Adjustment				27.8		27.8					0.0
April 2029 Senior Notes | Senior Notes
Business Acquisition, Pro Forma Information
Senior notes				450.0		450.0				$ 450.0	0.0
Crestwood Midstream Partners LP
Business Acquisition [Line Items]
Investments in unconsolidated affiliates				121.4		121.4					155.8
Goodwill				251.3		251.3					138.6
Gain on acquisition				75.3	0.0	75.3	$ 0.0
Revenues				1,566.0	1,226.3	4,597.8	3,188.6
Net income (loss)				(113.0)	$ (41.8)	(107.4)	(120.7)
Business Acquisition, Pro Forma Information
Revenues				1,398.3		4,832.0	3,626.1
Net income (loss)				(25.8)		(156.2)	$ (69.8)
Crestwood Midstream Partners LP | Barnett Shale Assets | Discontinued Operations, Disposed of by Sale
Business Acquisition, Pro Forma Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)		346.9
Asset Retirement Obligation, Period Increase (Decrease)		18.9
Crestwood Midstream Partners LP | Gathering and Processing South | Barnett Shale Assets | Disposal Group, Not Discontinued Operations
Business Acquisition, Pro Forma Information
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal						53.0
Crestwood Midstream Partners LP | Gathering and Processing South | Marcellus Shale Assets | Disposal Group, Held-for-sale, Not Discontinued Operations
Business Acquisition, Pro Forma Information
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal				248.2
Crestwood Midstream Partners LP | April 2029 Senior Notes
Business Acquisition, Pro Forma Information
Senior notes				477.8		477.8					$ 0.0
Crestwood Equity Partners LP | Barnett Shale Assets | Discontinued Operations, Disposed of by Sale
Business Acquisition, Pro Forma Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)		221.9
Asset Retirement Obligation, Period Increase (Decrease)		$ 18.9
Crestwood Equity Partners LP | Gathering and Processing South | Barnett Shale Assets | Disposal Group, Not Discontinued Operations
Business Acquisition, Pro Forma Information
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal						72.0
Crestwood Permian Basin Holdings LLC
Business Acquisition, Pro Forma Information
Business Acquisition, Percentage of Additional Voting Interests Acquired	50.00%
Crestwood Permian Basin Holdings LLC | First Reserve Management, L.P.
Business Acquisition, Pro Forma Information
Business Acquisition, Percentage of Additional Voting Interests Acquired	50.00%
Oasis Midstream Partners LP
Business Acquisition [Line Items]
Cash payment			$ 160.0
Discount rate										12.00%
Cash			14.9
Other current assets			63.2
Property, plant and equipment			1,264.4
Intangible assets			464.0
Total assets acquired			1,806.5
Current liabilities			48.2
Long-term debt			698.7
Other long-term liabilities			25.8
Total liabilities assumed			772.7
Net assets acquired excluding goodwill			1,033.8
Goodwill			56.2
Net assets acquired			$ 1,090.0
Revenues				110.8		275.1
Net income (loss)				37.7		94.0
Business Acquisition, Pro Forma Information
Weighted average remaining life			20 years
Debt Instrument, Fair Value Adjustment			$ 30.7							$ 30.7
Asset Retirement Obligation			16.1
Consideration transferred			1,800.0
Business Combination, Acquisition Related Costs						20.1
Oasis Midstream Partners LP | Gathering and Processing North
Business Acquisition [Line Items]
Goodwill			48.8
Oasis Midstream Partners LP | Gathering and Processing South
Business Acquisition [Line Items]
Goodwill			7.4
Oasis Midstream Partners LP | Revolving Credit Facility
Business Acquisition, Pro Forma Information
CMLP Credit Facility			218.0
Oasis Midstream Partners LP | April 2029 Senior Notes | Senior Notes
Business Acquisition, Pro Forma Information
Senior notes			450.0
Oasis Midstream Partners LP | Oasis Petroleum Inc.
Business Acquisition [Line Items]
Cash payment			$ 150.0
Issued shares (in shares)			20.9
Stock exchanged (in shares)			33.8
Oasis Midstream Partners LP | Oasis Midstream Partners LP
Business Acquisition [Line Items]
Stock exchanged (in shares)			14.8
Oasis Midstream Partners LP | Oasis Midstream Public Unitholders
Business Acquisition [Line Items]
Issued shares (in shares)			12.9
Oasis Midstream Partners LP | Oasis Petroleum General Partners
Business Acquisition [Line Items]
Cash payment			$ 10.0
Sendero Midstream Partners, LP
Business Acquisition [Line Items]
Cash payment	$ 631.2
Discount rate	13.00%
Cash	$ 28.5
Other current assets	77.9
Property, plant and equipment	440.2
Intangible assets	138.9
Other non-current assets	0.2
Total assets acquired	685.7
Current liabilities	64.1
Long-term liabilities(1)	17.8
Long-term liabilities(1)	14.0
Total liabilities assumed	81.9
Net assets acquired excluding goodwill	603.8
Goodwill	27.4
Net assets acquired	$ 631.2
Revenues				159.0		159.0
Net income (loss)				18.1		18.1
Business Acquisition, Pro Forma Information
CMLP Credit Facility				631.2		631.2
Weighted average remaining life	20 years
Business Combination, Acquisition Related Costs				8.4		9.3
Acquired Finite Lived Intangible Liabilities Weighted Average Useful Life	8 years
Crestwood Permian Basin Holdings LLC
Business Acquisition [Line Items]
Discount rate	15.00%
Cash	$ 149.4
Other current assets	83.3
Property, plant and equipment	453.4
Intangible assets	16.5
Other non-current assets	4.9
Total assets acquired	815.2
Current liabilities	80.4
Long-term liabilities(1)	38.9
Long-term debt	140.2
Other long-term liabilities	47.9
Total liabilities assumed	268.5
Net assets acquired excluding goodwill	546.7
Investments in unconsolidated affiliates	78.6
Gain on acquisition of Crestwood Permian	75.3
Goodwill	29.1
Total purchase price	276.7
Gain on acquisition	$ 75.3
Revenues				157.0		157.0
Net income (loss)				8.4		8.4
Business Acquisition, Pro Forma Information
Weighted average remaining life	20 years
Business Combination, Acquisition Related Costs				$ 0.1		$ 0.3
Acquired Finite Lived Intangible Liabilities Weighted Average Useful Life	10 years
Crestwood Permian Basin Holdings LLC | Crestwood Permian Basin Holdings LLC
Business Acquisition [Line Items]
Investments in unconsolidated affiliates	$ 194.7
Crestwood Permian Basin Holdings LLC | Crestwood Equity Partners LP
Business Acquisition, Pro Forma Information
Percentage of voting rights acquired	100.00%
Crestwood Permian Basin Holdings LLC | First Reserve Management, L.P.
Business Acquisition [Line Items]
Cash payment	$ 5.9
Issued shares (in shares)	11.3

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Certain Balance Sheet Information (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Accrued Expenses and Other Liabilities [Line Items]
Operating leases	$ 8.2	$ 13.2
Finance leases	2.2	1.7
Contract liabilities	12.2	10.7
Total CMLP accrued expenses and other liabilities	204.5	147.1
Contract liabilities	209.1	187.1
Intangible liabilities	51.7	0.0
Operating leases	14.5	19.4
Other long-term liabilities	325.7	258.7
Crestwood Midstream Partners LP
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	71.9	66.3
Accrued property taxes	8.5	4.4
Income tax payable	0.7	0.4
Interest payable	56.6	30.6
Accrued additions to property, plant and equipment	42.6	17.4
Operating leases	8.2	13.2
Finance leases	2.2	1.7
Contract liabilities	12.2	10.7
Asset retirement obligations	0.4	1.4
Total CMLP accrued expenses and other liabilities	203.3	146.1
Contract liabilities	209.1	187.1
Operating leases	14.5	19.4
Asset retirement obligations	33.9	34.8
Other long-term liabilities	323.6	254.1
Crestwood Midstream Partners LP | Other
Accrued Expenses and Other Liabilities [Line Items]
Other long-term liabilities	14.4	12.8
Crestwood Equity Partners LP
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	1.1	0.9
Income tax payable	0.1	0.1
Total CMLP accrued expenses and other liabilities	204.5	147.1
Other long-term liabilities	325.7	258.7
Crestwood Equity Partners LP | Other
Accrued Expenses and Other Liabilities [Line Items]
Other long-term liabilities	$ 2.1	$ 4.6

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Investments in Unconsolidated Affiliates (Net Investments In and Earnings (Loss) from Unconsolidated Affiliates) (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Oct. 31, 2022	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Jul. 11, 2022	Jul. 10, 2022	Dec. 31, 2021	Jul. 31, 2021
Schedule of Equity Method Investments [Line Items]
Investment		$ 121.4		$ 121.4				$ 155.8
Earnings (loss) from unconsolidated affiliates, net		3.2	$ 4.9	12.2	$ (125.9)
Payments to acquire equity method investments				90.2	10.2
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investment						$ 78.6
Crestwood Equity Partners LP | Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Percentage of voting rights acquired						100.00%
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Business Acquisition, Percentage of Additional Voting Interests Acquired						50.00%
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investment		0.0		0.0		$ 194.7		116.1
Earnings (loss) from unconsolidated affiliates, net		1.3	4.2	8.7	4.4
Ownership percentage						50.00%	50.00%
Payments to acquire equity method investments				83.5	3.3
Crestwood Permian Basin Holdings LLC | Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investment						$ 194.7
Crestwood Permian Basin LLC
Schedule of Equity Method Investments [Line Items]
Investment		77.1		77.1				0.0
Earnings (loss) from unconsolidated affiliates, net		0.7	0.0	0.7	0.0
Difference between carrying amount and underlying equity		2.3		2.3
Amortization		0.1		0.1
Payments to acquire equity method investments				0.0	0.0
Crestwood Permian Basin LLC | Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage						50.00%
Crestwood Permian Basin LLC | Shell Midstream Partners L.P.
Schedule of Equity Method Investments [Line Items]
Ownership percentage						50.00%
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investment		41.2		41.2				36.2
Earnings (loss) from unconsolidated affiliates, net		1.3	(0.1)	3.2	9.1
Difference between carrying amount and underlying equity		20.6		20.6
Amortization		0.3	0.3	0.9	0.9
Payments to acquire equity method investments				6.7	6.9
Tres Palacios Holdings LLC | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments	$ 0.4
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Investment		3.1		3.1				3.5
Earnings (loss) from unconsolidated affiliates, net		(0.1)	(0.1)	(0.4)	0.0
Payments to acquire equity method investments				0.0	0.0
Powder River Basin Industrial Complex, LLC | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments	$ 0.3
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Investment		0.0		0.0				$ 0.0
Earnings (loss) from unconsolidated affiliates, net		$ 0.0	0.9	0.0	(139.4)
Difference between carrying amount and underlying equity			$ 51.3		51.3
Ownership percentage								50.00%
Equity Method Investment Transaction Costs									$ 3.0
Payments to acquire equity method investments				$ 0.0	0.0
Stagecoach Gas Services LLC | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Schedule of Equity Method Investments [Line Items]
Earnings (loss) from unconsolidated affiliates, net					$ 155.4

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Investments in Unconsolidated Affiliates (Distributions and Contributions) (Details) - USD ($) $ in Millions	1 Months Ended		9 Months Ended
	Oct. 31, 2022	Jul. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments			$ 20.7	$ 663.0
Payments to acquire equity method investments			90.2	10.2
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments			13.6	8.9
Payments to acquire equity method investments			83.5	3.3
Crestwood Permian Basin LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments			2.2	0.0
Payments to acquire equity method investments			0.0	0.0
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments			4.9	13.1
Payments to acquire equity method investments			6.7	6.9
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments			0.0	0.1
Payments to acquire equity method investments			0.0	0.0
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		$ 613.9	0.0	640.9
Payments to acquire equity method investments			$ 0.0	$ 0.0
Subsequent Event | Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments	$ 3.9
Payments to acquire equity method investments	0.4
Subsequent Event | Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments	$ 0.3

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Risk Management (Risk Management Activities) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Product revenues	$ 84.7	$ 129.4	$ 395.7	$ 296.9
Commodity contract
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative instruments not designated as hedging	$ 45.0	$ (53.4)	$ (6.3)	$ (94.8)

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Risk Management (Notional Amounts and Terms of Company's Derivative Financial Instruments) (Details) bcf in Millions, MMBbls in Millions	Sep. 30, 2022 MMBbls bcf	Dec. 31, 2021 bcf MMBbls
Propane, ethane, butane, heating oil and crude oil (MMBbls) | Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount | MMBbls	66.1	71.6
Propane, ethane, butane, heating oil and crude oil (MMBbls) | Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount | MMBbls	69.8	75.8
Natural gas (Bcf) | Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount | bcf	38.0	31.9
Natural gas (Bcf) | Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount | bcf	43.2	43.4

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Risk Management (Schedule of Derivative Instruments in Statement of Financial Position, Fair Value) (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Derivative [Line Items]
Cash collateral received, net	$ 29.7	$ 11.4
Commodity contract
Derivative [Line Items]
Cash collateral received, net	7.2	1.5
Commodity contract with credit contingent features
Derivative [Line Items]
Aggregate fair value of commodity derivative instruments	15.6	57.9
Variation Margin-Related Net Derivative Asset Position
Derivative [Line Items]
Derivative Liability	(24.0)
Broker-related net derivative asset (liability) position		104.8
Variation Margin-Related Cash Collateral Received
Derivative [Line Items]
Broker-related cash collateral posted (received)	$ (57.4)	$ (76.8)

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Risk Management (Narrative) (Details) - Price Risk Contracts Member - Maximum	9 Months Ended
	Sep. 30, 2022
Derivative [Line Items]
Remaining maturity	36 months
Percent of contracts expiring in the next twelve months	88.00%

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Fair Value Measurements (Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	$ 693.0	$ 728.9
Other investments	2.4	2.2
Assets, Fair Value Disclosure, Excluding Netting Adjustments	695.4	731.1
Netting agreements	(584.5)	(607.4)
Assets, Collateral/Margin Received or Paid	4.2	79.4
Assets from price risk management, total	112.7	42.1
Total assets at fair value	115.1	44.3
Liabilities from price risk management	644.9	713.2
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	644.9	713.2
Netting agreements	(584.5)	(607.4)
Liabilities, Collateral/Margin Received or Paid	(23.5)	(8.8)
Liabilities from price risk management, total	36.9	114.6
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	36.7	33.3
Other investments	2.4	2.2
Assets, Fair Value Disclosure, Excluding Netting Adjustments	39.1	35.5
Liabilities from price risk management	49.7	26.9
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	49.7	26.9
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	656.3	695.6
Other investments	0.0	0.0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	656.3	695.6
Liabilities from price risk management	595.2	686.3
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	595.2	686.3
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	0.0	0.0
Other investments	0.0	0.0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	0.0	0.0
Liabilities from price risk management	0.0	0.0
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	$ 0.0	$ 0.0

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Fair Value Measurements (Schedule of Carrying Values and Estimated Fair Values of Senior Notes) (Details) - Crestwood Midstream Partners LP - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
2025 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	$ 497.3	$ 496.5
Fair Value	473.5	511.9
2027 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	595.1	594.2
Fair Value	545.6	615.0
February 2029 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	691.8	690.8
Fair Value	627.2	727.3
April 2029 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	477.8	0.0
Fair Value	$ 433.1	$ 0.0

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Long-Term Debt (Components Of Long-Term Debt) (Details) - USD ($) $ in Millions	Sep. 30, 2022	Feb. 28, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Less: deferred financing costs, net	$ 27.1		$ 29.9
Total debt	3,570.0		2,052.3
Less: current portion	0.0		0.2
Total long-term debt, less current portion	3,570.0		2,052.1
April 2029 Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Fair Value Adjustment	27.8		0.0
Senior Notes | 2025 Senior Notes
Debt Instrument [Line Items]
Senior notes	500.0		500.0
Senior Notes | 2027 Senior Notes
Debt Instrument [Line Items]
Senior notes	600.0		600.0
Senior Notes | February 2029 Senior Notes
Debt Instrument [Line Items]
Senior notes	700.0		700.0
Senior Notes | April 2029 Senior Notes
Debt Instrument [Line Items]
Senior notes	450.0	$ 450.0	0.0
Other
Debt Instrument [Line Items]
Other	0.0		0.2
Revolving Credit Facility | Crestwood Midstream Revolver
Debt Instrument [Line Items]
CMLP Credit Facility	1,102.6		282.0
Revolving Credit Facility | CPBH Credit Facility
Debt Instrument [Line Items]
CMLP Credit Facility	$ 216.7		$ 0.0

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Long-Term Debt (Narrative) (Details)			1 Months Ended	3 Months Ended		9 Months Ended
	Jul. 11, 2022 USD ($)	Feb. 01, 2022 USD ($)	Jan. 31, 2021 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Oct. 31, 2022 USD ($)	Feb. 28, 2022 USD ($)	Dec. 31, 2021 USD ($)
Debt Instrument [Line Items]
Debt Instrument, Term						5 years
Senior Secured Leverage Ratio, maximum				3.50		3.50
Senior Secured Leverage Ratio				1.29		1.29
Extinguishment of Debt, Amount							$ 687,200,000
Loss on modification/extinguishment of debt				$ 0	$ 0	$ 0	6,700,000
Amortization of Debt Discount (Premium)				1,100,000		2,900,000
Interest paid							8,600,000
Oasis Midstream Partners LP
Debt Instrument [Line Items]
Cash payment		$ 160,000,000
Debt Instrument, Fair Value Adjustment		30,700,000							$ 30,700,000
Sendero Midstream Partners, LP
Debt Instrument [Line Items]
CMLP Credit Facility				631,200,000		631,200,000
Cash payment	$ 631,200,000
Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Loss on modification/extinguishment of debt				0	$ 0	0	$ 6,700,000
2027 Senior Notes | Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Senior notes				595,100,000		595,100,000				$ 594,200,000
2025 Senior Notes | Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Senior notes				497,300,000		$ 497,300,000				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]
CMLP Credit Facility				1,102,600,000		$ 1,102,600,000				282,000,000.0
Available capacity				382,600,000		382,600,000
Letters of credit outstanding				$ 14,800,000		$ 14,800,000				$ 6,300,000
Debt, Weighted Average Interest Rate				4.97%		4.97%				1.91%
Interest Coverage Ratio Minimum						2.50
Total Funded Debt to Consolidated Ebitda						3.93
Consolidated Ebitda To Consolidated Interest Expense						5.11
Crestwood Midstream Revolver | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate				4.70%		4.70%				1.90%
Crestwood Midstream Revolver | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate				7.25%		7.25%				4.00%
Revolving Credit Facility | Oasis Midstream Partners LP
Debt Instrument [Line Items]
CMLP Credit Facility		218,000,000
April 2029 Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Fair Value Adjustment				$ 27,800,000		$ 27,800,000				$ 0
April 2029 Senior Notes | Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Senior notes				477,800,000		$ 477,800,000				0
Oasis Midstream Partners LP | Revolving Credit Facility
Debt Instrument [Line Items]
CMLP Credit Facility		218,000,000
CPBH Credit Facility
Debt Instrument [Line Items]
Consolidated Leverage Ratio Maximum						5.00
Line of Credit Facility Additional Potential Capacity				85,000,000		$ 85,000,000
CPBH Credit Facility | Minimum
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Percentage						0.375%
CPBH Credit Facility | Maximum
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Percentage						0.50%
CPBH Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
CMLP Credit Facility				216,700,000		$ 216,700,000				0
Available capacity				$ 13,300,000		$ 13,300,000
Debt, Weighted Average Interest Rate				5.92%		5.92%
Interest Coverage Ratio Minimum						2.50
Total Funded Debt to Consolidated Ebitda						3.21
Consolidated Ebitda To Consolidated Interest Expense						13.19
CPBH Credit Facility | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate				5.20%		5.20%
CPBH Credit Facility | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate				7.75%		7.75%
Senior Notes | 2027 Senior Notes
Debt Instrument [Line Items]
Senior notes				$ 600,000,000.0		$ 600,000,000.0				600,000,000.0
Senior Notes | 2025 Senior Notes
Debt Instrument [Line Items]
Senior notes				500,000,000.0		500,000,000.0				500,000,000.0
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				450,000,000.0		450,000,000.0			$ 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		1,500,000,000
Revolving Loan Facility | CPBH Credit Facility
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity				$ 230,000,000		$ 230,000,000
CPBH Credit Facility | Revolving Credit Facility | Federal Funds Rate
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate						0.50%
CPBH Credit Facility | Revolving Credit Facility | Secured Overnight Financing Rate
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate						1.00%
CPBH Credit Facility | Revolving Credit Facility | Minimum | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate						2.50%
CPBH Credit Facility | Revolving Credit Facility | Maximum | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate						3.50%
Revolving Credit Facility | CPBH Credit Facility | Minimum | Secured Overnight Financing Rate
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate						1.50%
Revolving Credit Facility | CPBH Credit Facility | Maximum | Secured Overnight Financing Rate
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate						2.50%
Subsequent Event | Revolving Loan Facility | Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity								$ 1,750,000,000

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Commitments and Contingencies (Details) - USD ($) $ in Millions		9 Months Ended	30 Months Ended
	Oct. 24, 2022	Sep. 30, 2022	Jun. 30, 2022	Dec. 31, 2021
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Damages paid		$ 3.2	$ 22.7
Accrued amounts for outstanding legal matters		29.8		$ 16.8
Subsequent Event
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Damages Awarded, Value	$ 20.7
Loss Contingency Damages Awarded Pre-Judgement Attorney Fees and Costs Value	4.7
Loss Contingency Damages Awarded Pre-Judgement Interest Award Value	$ 17.7
Crestwood Midstream Partners LP
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Self-insurance reserves		$ 4.5		$ 4.7

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Commitments and Contingencies (Environmental Compliance) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Site Contingency [Line Items]
Insurance Settlements Receivable	$ 3.7
Fort Berthold Indian Reservation
Site Contingency [Line Items]
Accrual of environmental loss contingencies	4.2	$ 1.0
Maximum | Fort Berthold Indian Reservation
Site Contingency [Line Items]
Potential liability for environmental exposures	5.2
Minimum | Fort Berthold Indian Reservation
Site Contingency [Line Items]
Potential liability for environmental exposures	$ 4.2

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Commitments and Contingencies (Self Insurance) (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Crestwood Equity Partners LP
Other Commitments [Line Items]
Self-insurance reserves	$ 5.4	$ 5.5
Self-insurance reserves expected to be paid	3.5
Crestwood Midstream Partners LP
Other Commitments [Line Items]
Self-insurance reserves	4.5	$ 4.7
Self-insurance reserves expected to be paid	$ 2.9

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Leases (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Apr. 30, 2022	Dec. 31, 2021
Lessee, Lease, Description [Line Items]
Operating lease right-of-use assets, net	$ 18.6		$ 18.6			$ 27.4
Operating leases	8.2		8.2			13.2
Operating leases	14.5		14.5			19.4
Total operating lease liabilities	22.7		22.7			32.6
Finance Lease, Right-of-Use Asset, before Accumulated Amortization	14.6		14.6			12.3
Property, plant and equipment	5,141.4		5,141.4			3,771.5
Finance Lease, Right-of-Use Asset, Accumulated Amortization	9.5		9.5			9.2
Less: accumulated depreciation	752.1		752.1			992.1
Finance Lease, Right-of-Use Asset, after Accumulated Amortization	5.1		5.1			3.1
Property, plant and equipment, net	4,389.3		4,389.3			2,779.4
Finance leases	2.2		2.2			1.7
Finance Lease, Liability, Noncurrent	2.7		2.7			1.2
Finance Lease, Liability	4.9		4.9			$ 2.9
Operating lease expense	3.4	$ 3.7	9.2	$ 12.8
Finance lease expense	$ 0.9	0.8	$ 2.7	2.6
Operating lease, liability, current, extensible enumeration	Accrued expenses and other liabilities		Accrued expenses and other liabilities			Accrued expenses and other liabilities
Finance lease, liability, noncurrent, extensible enumeration	Other long-term liabilities		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			Accrued expenses and other liabilities
Operating lease, liability, noncurrent, extensible enumeration	Other long-term liabilities		Other long-term liabilities			Other long-term liabilities
Loss on long-lived assets, net	$ 175.9	$ 18.5	$ 186.9	$ 19.6
Disposal Group, Disposed of by Sale, Not Discontinued Operations
Lessee, Lease, Description [Line Items]
Disposal Group, Including Discontinued Operation, Consideration					$ 24.7
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal			$ 4.1

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Partners' Capital (Schedule of Partners' Capital Account, Distributions) (Details) - USD ($) $ / shares in Units, $ in Millions													9 Months Ended
	Aug. 12, 2022	Aug. 05, 2022	May 13, 2022	May 06, 2022	Feb. 14, 2022	Feb. 07, 2022	Aug. 13, 2021	Aug. 06, 2021	May 14, 2021	May 07, 2021	Feb. 12, 2021	Feb. 05, 2021	Sep. 30, 2022	Sep. 30, 2021
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Date of Record		Aug. 05, 2022		May 06, 2022		Feb. 07, 2022		Aug. 06, 2021		May 07, 2021		Feb. 05, 2021
Distribution Made to Limited Partner, Distribution Date	Aug. 12, 2022		May 13, 2022		Feb. 14, 2022		Aug. 13, 2021		May 14, 2021		Feb. 12, 2021
Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit	$ 0.655		$ 0.655		$ 0.625		$ 0.625		$ 0.625		$ 0.625
Distribution Made to Limited Partner, Cash Distributions Paid	$ 71.6		$ 64.2		$ 60.9		$ 39.3		$ 39.3		$ 46.4		$ 196.7	$ 125.0

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Partners' Capital (Components of Net Income (Loss) Attributable to Non-Controlling Interests) (Details) $ in Millions	1 Months Ended
	Oct. 31, 2022 USD ($)
Crestwood Niobrara LLC | Subsequent Event
Distribution Made to Limited Partner [Line Items]
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	$ (10.3)

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Partners' Capital (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions																			1 Months Ended		3 Months Ended			9 Months Ended
	Nov. 14, 2022	Nov. 07, 2022	Oct. 20, 2022	Sep. 15, 2022	Aug. 12, 2022	Aug. 05, 2022	Jul. 11, 2022	May 13, 2022	May 06, 2022	Feb. 14, 2022	Feb. 07, 2022	Feb. 01, 2022	Aug. 13, 2021	Aug. 06, 2021	May 14, 2021	May 07, 2021	Feb. 12, 2021	Feb. 05, 2021	Feb. 28, 2022	Mar. 31, 2021	Sep. 30, 2022	Mar. 31, 2022	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distribution Date					Aug. 12, 2022			May 13, 2022		Feb. 14, 2022			Aug. 13, 2021		May 14, 2021		Feb. 12, 2021
Distribution Made to Limited Partner, Date of Record						Aug. 05, 2022			May 06, 2022		Feb. 07, 2022			Aug. 06, 2021		May 07, 2021		Feb. 05, 2021
Distributions to preferred unitholders																								$ 45.0	$ 45.0
Incentive Distribution, Distribution																								196.7	125.0
Distributions to non-controlling partner																								31.0	29.9
Distribution Made to Limited Partner, Cash Distributions Paid					$ 71.6			$ 64.2		$ 60.9			$ 39.3		$ 39.3		$ 46.4							196.7	125.0
Noncash Distribution to Parent																									2.4
Partners' Capital Account, Treasury Units, Purchased				$ 123.7																$ 268.0
Oasis Midstream Partners LP
Distribution Made to Limited Partner [Line Items]
Cash payment												$ 160.0
Common Units
Distribution Made to Limited Partner [Line Items]
Stock exchanged (in shares)				4,600,000																11,500,000
Treasury Stock, Shares, Retired																					4,600,000		11,500,000
Subordinated Units
Distribution Made to Limited Partner [Line Items]
Stock exchanged (in shares)																				400,000
Treasury Stock, Shares, Retired																							400,000
Crestwood Midstream Partners LP
Distribution Made to Limited Partner [Line Items]
Incentive Distribution, Distribution																								537.6	451.3
Distributions to non-controlling partner																								31.0	29.9
Distribution Made to General Partner, Cash Distributions Paid																								$ 537.6	451.3
Crestwood Permian Basin Holdings LLC
Distribution Made to Limited Partner [Line Items]
Business Acquisition, Percentage of Additional Voting Interests Acquired							50.00%
Crestwood Permian Basin Holdings LLC | First Reserve Management, L.P.
Distribution Made to Limited Partner [Line Items]
Business Acquisition, Percentage of Additional Voting Interests Acquired							50.00%
Common unit
Distribution Made to Limited Partner [Line Items]
Transaction Costs																									$ 7.6
Partners' Capital Account, Treasury Units, Purchased																					$ 123.7
Partners' Capital
Distribution Made to Limited Partner [Line Items]
Partners' Capital Account, Treasury Units, Purchased																					123.7
Partners' Capital | Crestwood Midstream Partners LP
Distribution Made to Limited Partner [Line Items]
Non-cash contribution from partner (Note 11)							$ 127.3					1,075.1									127.3	$ 1,075.1
Cash contribution from partner (Note 11)							$ 149.4					$ 14.9									149.4	$ 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
Oasis Petroleum Inc. | Oasis Midstream Partners LP
Distribution Made to Limited Partner [Line Items]
Issued shares (in shares)												20,900,000
Cash payment												$ 150.0
First Reserve Management, L.P. | Crestwood Permian Basin Holdings LLC
Distribution Made to Limited Partner [Line Items]
Issued shares (in shares)							11,300,000
Cash payment							$ 5.9
Subsequent Event
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distribution Date	Nov. 14, 2022
Distribution Made to Limited Partner, Date of Record		Nov. 07, 2022
Distributions to preferred unitholders			$ 15.0
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																					3.8			$ 3.8
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																					$ 0.4			$ 1.1
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period																								3 years

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Partners' Capital Rollforward of non-controlling interest (Details) - USD ($) $ in Millions	1 Months Ended	9 Months Ended
	Oct. 31, 2022	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021	Dec. 31, 2020
Increase (Decrease) in Temporary Equity [Roll Forward]
Temporary Equity, Net Income		$ 30.8	$ 30.7
Interest of non-controlling partner in subsidiary		434.4	434.5	$ 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		$ (31.0)	$ (29.9)

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Earnings Per Limited Partner Unit (Details) - shares shares in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 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	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	0.1	0.2	0.2	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	0.0	0.0	0.1
Crestwood Niobrara LLC | Niobrara 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	3.9	3.9	3.9	3.9

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Segments (Reconciliation of Net Income (Loss) to EBITDA) (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($) segment	Sep. 30, 2021 USD ($)
Segment Reporting, Other Significant Reconciling Item [Line Items]
Number of Operating Segments | segment			3
Net income (loss)	$ (43.0)	$ (39.6)	$ 18.6	$ (116.0)
Interest and debt expense, net	47.6	30.9	123.8	102.0
Provision for income taxes	1.4	0.1	1.7	0.1
Depreciation, amortization and accretion	86.9	64.6	242.3	182.6
EBITDA	92.9	56.0	386.4	175.4
Loss on modification/extinguishment of debt	0.0	0.0	0.0	6.7
Gain (loss) on long-lived assets	(175.9)	(18.5)	(186.9)	(19.6)
Eliminations
Segment Reporting, Other Significant Reconciling Item [Line Items]
Gain (loss) on long-lived assets			53.0
Crestwood Midstream Partners LP
Segment Reporting, Other Significant Reconciling Item [Line Items]
Net income (loss)	(113.0)	(41.8)	(107.4)	(120.7)
Interest and debt expense, net	47.6	30.9	123.8	102.0
Provision for income taxes	1.4	0.1	1.6	0.1
Depreciation, amortization and accretion	86.8	68.2	248.0	193.2
EBITDA	22.8	57.4	266.0	181.3
Loss on modification/extinguishment of debt	0.0	0.0	0.0	6.7
Gain (loss) on long-lived assets	$ (247.6)	$ (18.5)	$ (311.9)	$ (19.6)

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Segments (Summary Of Segment Information) (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($) segment	Sep. 30, 2021 USD ($)	Dec. 31, 2021 USD ($)
Net income (loss)	$ (43.0)	$ (39.6)	$ 18.6	$ (116.0)
Number of Operating Segments | segment			3
Depreciation, amortization and accretion	86.9	64.6	$ 242.3	182.6
Segment Reporting Information, Additional Information [Abstract]
Revenues	1,566.0	1,226.3	4,597.8	3,188.6
Costs of product/services sold	1,286.8	1,099.3	3,864.4	2,710.3
Operations and maintenance	55.0	31.6	144.0	90.2
General and administrative	33.9	25.9	103.8	67.4
Gain (loss) on long-lived assets	(175.9)	(18.5)	(186.9)	(19.6)
Gain on acquisition	75.3	0.0	75.3	0.0
Earnings (loss) from unconsolidated affiliates, net	3.2	4.9	12.2	(125.9)
Other income, net	0.0	0.1	0.2	0.2
EBITDA	92.9	56.0	386.4	175.4
Assets	6,899.4		6,899.4		$ 4,445.7
Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Revenues	(280.0)	(125.6)	(559.0)	(315.1)
Gathering and Processing North | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Revenues	414.8	270.1	1,208.4	738.0
Gathering and Processing South | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Revenues	315.2	26.7	381.2	76.0
Storage and Logistics | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Revenues	1,116.0	1,055.1	3,567.2	2,689.7
Crestwood Midstream Partners LP
Net income (loss)	(113.0)	(41.8)	(107.4)	(120.7)
Depreciation, amortization and accretion	86.8	68.2	248.0	193.2
Segment Reporting Information, Additional Information [Abstract]
Revenues	1,566.0	1,226.3	4,597.8	3,188.6
Costs of product/services sold	1,286.8	1,099.3	3,864.4	2,710.3
Operations and maintenance	55.0	31.6	144.0	90.2
General and administrative	32.3	24.4	99.0	61.3
Gain (loss) on long-lived assets	(247.6)	(18.5)	(311.9)	(19.6)
Gain on acquisition	75.3	0.0	75.3	0.0
Earnings (loss) from unconsolidated affiliates, net	3.2	4.9	12.2	(125.9)
EBITDA	22.8	57.4	266.0	181.3
Assets	6,893.6		6,893.6		4,571.2
Crestwood Midstream Partners LP | Corporate, Non-Segment
Segment Reporting Information, Additional Information [Abstract]
Revenues	0.0	0.0	0.0	0.0
Costs of product/services sold	0.0	0.0	0.0	0.0
Operations and maintenance	0.0	0.0	0.0	0.0
General and administrative	32.3	24.4	99.0	61.3
Gain (loss) on long-lived assets	0.0	0.0	0.0	0.0
Gain on acquisition	0.0		0.0
Earnings (loss) from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
EBITDA	(32.3)	(24.4)	(99.0)	(61.3)
Assets	23.7		23.7		20.7
Crestwood Midstream Partners LP | Corporate and Eliminations [Member]
Segment Reporting Information, Additional Information [Abstract]
Revenues	0.0	0.0	0.0	0.0
Crestwood Midstream Partners LP | Gathering and Processing North | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Revenues	272.6	144.5	787.2	422.9
Costs of product/services sold	230.2	149.7	686.6	386.4
Operations and maintenance	27.4	14.1	78.6	38.2
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	0.0	0.1	0.0	0.2
Gain on acquisition	0.0		0.0
Earnings (loss) from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
EBITDA	157.2	106.4	443.2	313.6
Assets	4,072.4		4,072.4		2,408.0
Crestwood Midstream Partners LP | Gathering and Processing North | Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Revenues	142.2	125.6	421.2	315.1
Crestwood Midstream Partners LP | Gathering and Processing South | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Revenues	177.4	26.7	243.4	76.0
Costs of product/services sold	249.6	0.4	249.6	0.8
Operations and maintenance	14.3	5.4	28.6	17.4
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	(247.6)	(18.6)	(307.8)	(19.9)
Gain on acquisition	75.3		75.3
Earnings (loss) from unconsolidated affiliates, net	2.0	4.2	9.4	4.4
EBITDA	(119.0)	6.5	(120.1)	42.3
Assets	1,666.4		1,666.4		1,017.4
Crestwood Midstream Partners LP | Gathering and Processing South | Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Revenues	137.8	0.0	137.8	0.0
Crestwood Midstream Partners LP | Storage and Logistics | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Revenues	1,116.0	1,055.1	3,567.2	2,689.7
Costs of product/services sold	807.0	949.2	2,928.2	2,323.1
Operations and maintenance	13.3	12.1	36.8	34.6
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	0.0	0.0	(4.1)	0.1
Gain on acquisition	0.0		0.0
Earnings (loss) from unconsolidated affiliates, net	1.2	0.7	2.8	(130.3)
EBITDA	16.9	(31.1)	41.9	(113.3)
Assets	1,131.1		1,131.1		1,125.1
Crestwood Midstream Partners LP | Storage and Logistics | Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Revenues	(280.0)	(125.6)	(559.0)	(315.1)
Crestwood Equity Partners LP
Segment Reporting Information, Additional Information [Abstract]
General and administrative	1.6	1.5	4.8	6.1
Gain (loss) on long-lived assets	71.7		125.0
Other income, net		0.1	0.2	0.2
EBITDA	92.9	56.0	386.4	175.4
Assets	6,899.4		6,899.4		4,445.7
Crestwood Equity Partners LP | Barnett Shale Assets
Segment Reporting Information, Additional Information [Abstract]
Gain (loss) on long-lived assets			72.0
Crestwood Equity Partners LP | Corporate, Non-Segment
Segment Reporting Information, Additional Information [Abstract]
General and administrative	1.6	1.5	4.8	6.1
Gain (loss) on long-lived assets	0.0		0.0
Other income, net		0.1	0.2	0.2
EBITDA	(33.9)	(25.8)	(103.6)	(67.2)
Assets	29.5		29.5		26.1
Crestwood Equity Partners LP | Gathering and Processing North | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	0.0		0.0
Other income, net		0.0	0.0	0.0
EBITDA	157.2	106.4	443.2	313.6
Assets	4,072.4		4,072.4		2,408.0
Crestwood Equity Partners LP | Gathering and Processing South | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	71.7		125.0
Other income, net		0.0	0.0	0.0
EBITDA	(47.3)	6.5	4.9	42.3
Assets	1,666.4		1,666.4		886.5
Crestwood Equity Partners LP | Storage and Logistics | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	0.0		0.0
Other income, net		0.0	0.0	0.0
EBITDA	16.9	$ (31.1)	41.9	$ (113.3)
Assets	$ 1,131.1		$ 1,131.1		$ 1,125.1

XML

Segments (Narrative) (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($) segment	Sep. 30, 2021 USD ($)	Jul. 11, 2022	Jul. 10, 2022
Segment Reporting Information [Line Items]
Interest, taxes, depreciation and amortization included in earnings from equity method investments | $	$ 2.5	$ 4.9	$ 12.0	$ 182.4
Number of Operating Segments | segment			3
Crestwood Permian Basin Holdings LLC
Segment Reporting Information [Line Items]
Ownership percentage					50.00%	50.00%
Crestwood Equity Partners LP | Crestwood Permian Basin Holdings LLC
Segment Reporting Information [Line Items]
Percentage of voting rights acquired					100.00%
Crestwood Permian Basin Holdings LLC
Segment Reporting Information [Line Items]
Business Acquisition, Percentage of Additional Voting Interests Acquired					50.00%
Crestwood Permian Basin Holdings LLC | First Reserve Management, L.P.
Segment Reporting Information [Line Items]
Business Acquisition, Percentage of Additional Voting Interests Acquired					50.00%

XML

Revenues (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Revenue Recognition [Abstract]
ASC 606 accounts receivable	$ 456.4	$ 331.0

XML

Revenues (Contract Assets and Liabilities) (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2022	Dec. 31, 2021
Contract Assets and Contract Liabilities [Line Items]
Contract Assets (Non-current)	$ 5.6	$ 5.6	$ 1.3
Contract liabilities	12.2	12.2	10.7
Contract liabilities	209.1	209.1	$ 187.1
Contract with Customer, Liability, Revenue Recognized	4.0	11.2
Crestwood Permian Basin Holdings LLC
Contract Assets and Contract Liabilities [Line Items]
Contract Assets (Non-current)	$ 4.7	$ 4.7

XML

Revenues (Disaggregation of Revenue) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Disaggregation of Revenue [Line Items]
Revenues	$ 1,566.0	$ 1,226.3	$ 4,597.8	$ 3,188.6
Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	43.5	35.3	149.2	100.0
Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	16.4	17.1	48.2	56.2
Water Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	49.3	24.8	130.7	69.5
Natural Gas Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	25.5	7.2	61.9	21.5
Natural Gas Compression
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4.7	3.7	11.3	12.1
Crude Oil Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.7	0.1	1.9	0.4
NGL Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2.2	2.6	6.9	8.7
Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.6	0.6	1.5	2.0
Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.6	0.7	4.6	1.8
NGL Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5.0	4.1	16.3	12.5
Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1.2	0.4	3.4
Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	296.8	84.7	591.2	225.2
Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	473.9	411.6	1,491.3	1,161.5
NGL Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	557.3	501.6	1,676.6	1,212.7
Other revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.5	0.5	1.4	1.4
Water Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2.1		5.0
NGL Pipeline
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.1		0.2	0.1
Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenues	(280.0)	(125.6)	(559.0)	(315.1)
Intersegment Eliminations | Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Water Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Natural Gas Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Natural Gas Compression
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Crude Oil Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	(0.1)	(0.2)	(0.3)
Intersegment Eliminations | NGL Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	(0.1)	(0.1)	(0.1)
Intersegment Eliminations | NGL Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0.0	0.0	0.0
Intersegment Eliminations | Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(205.6)	(42.7)	(331.2)	(111.7)
Intersegment Eliminations | Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(9.8)	(25.1)	(33.9)	(62.5)
Intersegment Eliminations | NGL Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(58.9)	(57.6)	(187.9)	(140.5)
Intersegment Eliminations | Other revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(0.5)	0.0	(0.5)	0.0
Intersegment Eliminations | Water Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0		0.0
Intersegment Eliminations | NGL Pipeline
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(5.2)		(5.2)	0.0
Operating Segments | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenues	414.8	270.1	1,208.4	738.0
Operating Segments | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenues	315.2	26.7	381.2	76.0
Operating Segments | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenues	1,116.0	1,055.1	3,567.2	2,689.7
Operating Segments | Natural Gas Gathering | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	33.4	13.7	92.2	40.5
Operating Segments | Natural Gas Gathering | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	10.1	21.6	57.0	59.5
Operating Segments | Natural Gas Gathering | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Operating Segments | Crude Oil Gathering | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	14.7	17.1	43.6	56.2
Operating Segments | Crude Oil Gathering | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.7	0.0	4.6	0.0
Operating Segments | Crude Oil Gathering | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Operating Segments | Water Gathering | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	41.8	24.8	117.7	69.5
Operating Segments | Water Gathering | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	7.5	0.0	13.0	0.0
Operating Segments | Water Gathering | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Operating Segments | Natural Gas Processing | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	20.7	5.8	54.8	17.7
Operating Segments | Natural Gas Processing | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4.8	1.4	7.1	3.8
Operating Segments | Natural Gas Processing | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	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	0.0	0.0	0.0
Operating Segments | Natural Gas Compression | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4.7	3.7	11.3	12.1
Operating Segments | Natural Gas Compression | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Operating Segments | Crude Oil Storage | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.6	0.1	1.7	0.3
Operating Segments | Crude Oil Storage | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Operating Segments | Crude Oil Storage | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.1	0.1	0.4	0.4
Operating Segments | NGL Storage | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	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	0.0	0.0	0.0
Operating Segments | NGL Storage | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2.2	2.6	6.9	8.7
Operating Segments | Crude Oil Pipeline | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	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	0.0	0.0	0.0
Operating Segments | Crude Oil Pipeline | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.6	0.6	1.5	2.0
Operating Segments | Crude Oil Transportation | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.5	0.8	4.2	1.9
Operating Segments | Crude Oil Transportation | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.1	0.0	0.5	0.0
Operating Segments | Crude Oil Transportation | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	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	0.0	0.0	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	0.0	0.0	0.0
Operating Segments | NGL Transportation | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5.0	4.1	16.3	12.5
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	0.0	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	0.0	0.0
Operating Segments | Crude Oil Rail Loading | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1.2	0.4	3.4
Operating Segments | Natural Gas Product Sales | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	109.6	42.9	269.1	111.9
Operating Segments | Natural Gas Product Sales | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	144.4	0.0	145.3	0.6
Operating Segments | Natural Gas Product Sales | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	248.4	84.5	508.0	224.4
Operating Segments | Crude Oil Product Sales | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	120.9	105.4	394.9	297.1
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	0.0	0.0	0.0
Operating Segments | Crude Oil Product Sales | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	362.8	331.3	1,130.3	926.9
Operating Segments | NGL Product Sales | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	68.3	59.1	222.7	142.3
Operating Segments | NGL Product Sales | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	136.2	0.0	136.2	0.0
Operating Segments | NGL Product Sales | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	411.7	500.1	1,505.6	1,210.9
Operating Segments | Other revenue | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.8	0.0	1.4	0.0
Operating Segments | Other revenue | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Operating Segments | Other revenue | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.2	0.5	0.5	1.4
Operating Segments | Water Product Sales | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2.1		5.0
Operating Segments | Water Product Sales | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0		0.0
Operating Segments | Water Product Sales | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0		0.0
Operating Segments | NGL Pipeline | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0		0.0	0.0
Operating Segments | NGL Pipeline | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5.2		5.2	0.0
Operating Segments | NGL Pipeline | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.1		0.2	0.1
Revenue from Contract with Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,480.2	1,095.8	4,198.6	2,889.0
Revenue from Contract with Customer | Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(280.0)	(125.6)	(559.0)	(315.1)
Revenue from Contract with Customer | Operating Segments | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	414.4	269.7	1,207.3	737.4
Revenue from Contract with Customer | Operating Segments | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	314.7	26.7	380.2	76.0
Revenue from Contract with Customer | Operating Segments | Storage and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,031.1	925.0	3,170.1	2,390.7
Product and Service, Other
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	85.8	130.5	399.2	299.6
Product and Service, Other | Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	0.0	0.0	0.0	0.0
Product and Service, Other | Operating Segments | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	0.4	0.4	1.1	0.6
Product and Service, Other | Operating Segments | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	0.5	0.0	1.0	0.0
Product and Service, Other | Operating Segments | Storage and Logistics
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	$ 84.9	$ 130.1	$ 397.1	$ 299.0

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Revenues (Remaining Performance Obligations) (Details) $ in Millions	Sep. 30, 2022 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 143.6
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	3 months
Revenue, Remaining Performance Obligation, Amount	$ 23.3
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	$ 70.4
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	$ 45.8
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	$ 2.3
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

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Related Party Transactions (Details) - USD ($) shares in Thousands, $ in Millions		1 Months Ended	3 Months Ended		9 Months Ended
	Jul. 11, 2022	Sep. 30, 2022	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Jul. 10, 2022	Dec. 31, 2021
Related Party Transaction [Line Items]
Purchases of property, plant and equipment					$ 147.3	$ 55.8
Costs of product/services sold at CEQP and CMLP(2)			$ 51.3	$ 34.8	232.9	101.3
Operations and maintenance expenses charged by CEQP and CMLP			2.6	5.1	12.4	16.8
Related Party Transaction, Due from (to) Related Party [Abstract]
Related party receivables		$ 1.6	1.6		1.6			$ 8.2
Related party payables		$ 2.2	2.2		2.2			$ 12.0
Revenues			1,566.0	1,226.3	4,597.8	3,188.6
Crestwood Permian Basin Holdings LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues			157.0		157.0
First Reserve Management, L.P. | Crestwood Permian Basin Holdings LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Issued shares (in shares)	11,300
Chord Energy Corporation
Related Party Transaction, Due from (to) Related Party [Abstract]
Partners' Capital Account, Units, Treasury Units Purchased		4,600
Crestwood Equity Partners LP | Crestwood Permian Basin Holdings LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Percentage of voting rights acquired	100.00%
Product
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues			1,332.8	1,120.8	3,938.3	2,872.1
Service
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues			92.4	98.4	286.8	291.3
Applied Consultants, Inc.
Related Party Transaction [Line Items]
Purchases of property, plant and equipment						0.6
Crestwood Permian Basin Holdings LLC
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP			0.3	7.1	3.9	25.2
Costs of product/services sold at CEQP and CMLP(2)			9.2	30.4	116.8	75.5
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues			0.1		1.3
Tres Palacios Holdings LLC
Related Party Transaction [Line Items]
Costs of product/services sold at CEQP and CMLP(2)			0.3	0.2	1.7	11.3
Affiliated Entity
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP			140.8	7.1	372.7	25.2
Costs of product/services sold at CEQP and CMLP(2)			51.3	34.8	232.9	101.3
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party			8.5	11.9	23.5	24.4
Oasis Petroleum Inc.
Related Party Transaction [Line Items]
Costs of product/services sold at CEQP and CMLP(2)			41.5		114.1
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party			0.0	0.0	1.3	0.0
Oasis Petroleum Inc. | Product
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP			83.0		218.9
Oasis Petroleum Inc. | Service
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP			57.4		148.6
Ascent Resources - Utica, LLC
Related Party Transaction [Line Items]
Costs of product/services sold at CEQP and CMLP(2)				4.2		14.5
Crestwood Permian Basin LLC
Related Party Transaction [Line Items]
Costs of product/services sold at CEQP and CMLP(2)			0.3		0.3
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					146.6	55.8
Costs of product/services sold at CEQP and CMLP(2)			51.3	34.8	232.9	101.3
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues			1,566.0	1,226.3	4,597.8	3,188.6
Crestwood Midstream Partners LP | Product
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues			1,332.8	1,120.8	3,938.3	2,872.1
Crestwood Midstream Partners LP | Service
Related Party Transaction, Due from (to) Related Party [Abstract]
Revenues			92.4	98.4	286.8	291.3
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	1.0	3.3	3.0
Crestwood Permian Basin Holdings LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Business Acquisition, Percentage of Additional Voting Interests Acquired	50.00%
Crestwood LTIP | Crestwood Midstream Partners LP
Related Party Transaction [Line Items]
Share-based Payment Arrangement, Expense			9.6	12.9	26.8	27.4
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				0.1		3.4
Related Party Transaction, Due from (to) Related Party [Abstract]
Ownership percentage								50.00%
Tres Palacios Holdings LLC
Related Party Transaction [Line Items]
Operations and maintenance expenses charged by CEQP and CMLP			1.2	1.2	3.5	3.6
Crestwood Permian Basin Holdings LLC
Related Party Transaction [Line Items]
Operations and maintenance expenses charged by CEQP and CMLP			0.4	$ 3.8	7.9	$ 9.8
Related Party Transaction, Due from (to) Related Party [Abstract]
Ownership percentage	50.00%						50.00%
Crestwood Permian Basin LLC
Related Party Transaction [Line Items]
Operations and maintenance expenses charged by CEQP and CMLP			$ 1.0		$ 1.0