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, 2023

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 27, 2023).

Crestwood Equity Partners LP	105,098,724
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	14
Note 3. Acquisitions and Divestitures	14
Note 4. Certain Balance Sheet Information	15
Note 5. Investments in Unconsolidated Affiliates	16
Note 6. Risk Management	17
Note 7. Fair Value Measurements	19
Note 8. Long-Term Debt	21
Note 9. Commitments and Contingencies	22
Note 10. Leases	23
Note 11. Partners’ Capital and Non-Controlling Partner	24
Note 12. Earnings Per Limited Partner Unit	26
Note 13. Segments	27
Note 14. Revenues	30
Note 15. Related Party Transactions	34
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	36
Item 3. Quantitative and Qualitative Disclosures About Market Risk	46
Item 4. Controls and Procedures	46
Part II – Other Information
Item 1. Legal Proceedings	48
Item 1A. Risk Factors	48
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	48
Item 3. Defaults Upon Senior Securities	48
Item 4. Mine Safety Disclosures	48
Item 5. Other Information	48
Item 6. Exhibits	48
Signature	51

3

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements

CRESTWOOD EQUITY PARTNERS LP

CONSOLIDATED BALANCE SHEETS

(in millions, except unit information)

	September 30, 2023		December 31, 2022
	(unaudited)
Assets
Current assets:
Cash	$	23.8	$	7.5
Accounts receivable, less allowance for doubtful accounts of $0.5      at both September 30, 2023 and December 31, 2022	350.1		432.2
Inventory	179.9		122.6
Assets from price risk management activities	38.0		72.8
Prepaid expenses and other current assets	8.5		18.7
Total current assets	600.3		653.8
Property, plant and equipment	5,467.5		5,353.2
Less: accumulated depreciation	999.6		822.8
Property, plant and equipment, net	4,467.9		4,530.4
Intangible assets	1,234.6		1,306.3
Less: accumulated amortization	277.9		300.7
Intangible assets, net	956.7		1,005.6
Goodwill	223.0		223.0
Operating lease right-of-use assets, net	23.3		24.4
Investments in unconsolidated affiliates	77.1		119.5
Other non-current assets	11.5		10.3
Total assets	$	6,359.8	$	6,567.0
Liabilities and capital
Current liabilities:
Accounts payable	$	256.9	$	305.5
Accrued expenses and other liabilities	183.6		180.8
Liabilities from price risk management activities	17.6		23.9
Total current liabilities	458.1		510.2
Long-term debt, less current portion	3,302.5		3,378.3
Other long-term liabilities	323.4		333.4
Deferred income taxes	3.4		3.5
Total liabilities	4,087.4		4,225.4
Commitments and contingencies (Note 9)
Interest of non-controlling partner in subsidiary	456.0		434.4
Partners’ capital:
Crestwood Equity Partners LP partners’ capital (105,099,889 and 104,646,374 common units issued and outstanding at September 30, 2023 and December 31, 2022)	1,204.4		1,295.2
Preferred units (71,257,445 units issued and outstanding at both September 30, 2023 and December 31, 2022)	612.0		612.0
Total partners’ capital	1,816.4		1,907.2
Total liabilities and capital	$	6,359.8	$	6,567.0

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,
	2023		2022		2023		2022
Revenues:
Product revenues	$	989.2	$	1,332.8	$	2,991.5	$	3,938.3
Product revenues - related party (Note 15)	—		83.2		—		222.7
Service revenues	150.2		92.4		432.2		286.8
Service revenues - related party (Note 15)	—		57.6		—		150.0
Total revenues	1,139.4		1,566.0		3,423.7		4,597.8
Costs of product/services sold (exclusive of items shown separately below):
Product costs	898.1		1,228.6		2,668.1		3,613.4
Product costs - related party (Note 15)	—		51.3		0.5		232.9
Service costs	3.5		6.9		15.0		18.1
Total costs of products/services sold	901.6		1,286.8		2,683.6		3,864.4
Operating expenses and other:
Operations and maintenance	56.9		55.0		166.7		144.0
General and administrative	30.2		33.9		86.8		103.8
Depreciation, amortization and accretion	80.2		86.9		242.7		242.3
Loss on long-lived assets, net	2.6		175.9		4.8		186.9
Gain on acquisition	—		(75.3)		—		(75.3)
	169.9		276.4		501.0		601.7
Operating income	67.9		2.8		239.1		131.7
Earnings from unconsolidated affiliates, net	1.1		3.2		135.2		12.2
Interest and debt expense, net	(56.9)		(47.6)		(167.9)		(123.8)
Other income, net	0.2		—		0.3		0.2
Income (loss) before income taxes	12.3		(41.6)		206.7		20.3
Provision for income taxes	(0.2)		(1.4)		(1.1)		(1.7)
Net income (loss)	12.1		(43.0)		205.6		18.6
Net income attributable to non-controlling partner	32.1		10.3		52.6		30.8
Net income (loss) attributable to Crestwood Equity Partners LP	(20.0)		(53.3)		153.0		(12.2)
Net income attributable to preferred units	15.1		15.0		45.1		45.0
Net income (loss) attributable to partners	$	(35.1)	$	(68.3)	$	107.9	$	(57.2)
Net income (loss) per limited partner unit: (Note 12)
Basic	$	(0.33)	$	(0.64)	$	1.03	$	(0.59)
Diluted	$	(0.33)	$	(0.64)	$	0.99	$	(0.59)
Weighted-average limited partners’ units outstanding:
Basic	105.2		107.1		105.2		97.1
Dilutive	—		—		3.9		—
Diluted	105.2		107.1		109.1		97.1

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, 2022	71.3	$	612.0	104.6	$	1,295.2	$	1,907.2
Distributions to partners	—	(15.0)		—	(68.9)		(83.9)
Unit-based compensation	—	—		1.1	11.8		11.8
Taxes paid for unit-based compensation vesting	—	—		(0.5)	(14.8)		(14.8)
Other	—	—		0.1	1.6		1.6
Net income	—	15.0		—	16.4		31.4
Balance at March 31, 2023	71.3	$	612.0	105.3	$	1,241.3	$	1,853.3
Distributions to partners	—	(15.0)		—	(68.9)		(83.9)
Unit-based compensation	—	—		—	9.2		9.2
Taxes paid for unit-based compensation vesting	—	—		(0.1)	(0.8)		(0.8)
Other	—	—		—	(0.2)		(0.2)
Net income	—	15.0		—	126.6		141.6
Balance at June 30, 2023	71.3	$	612.0	105.2	$	1,307.2	$	1,919.2
Distributions to partners	—	(15.1)		—	(68.9)		(84.0)
Unit-based compensation	—	—		—	6.5		6.5
Taxes paid for unit-based compensation vesting	—	—		(0.1)	(4.9)		(4.9)
Other	—	—		—	(0.4)		(0.4)
Net income (loss)	—	15.1		—	(35.1)		(20.0)
Balance at September 30, 2023	71.3	$	612.0	105.1	$	1,204.4	$	1,816.4

6

CRESTWOOD EQUITY PARTNERS LP

CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL (continued)

(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	—	—		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	—	—		—	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	—	—		—	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

See accompanying notes.

7

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF CASH FLOWS (in millions) (unaudited)
	Nine Months Ended
	September 30,
	2023		2022
Operating activities
Net income	$	205.6	$	18.6
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	242.7		242.3
Amortization of debt-related deferred costs and fair value adjustment	2.5		1.7
Unit-based compensation	25.7		26.8
Loss on long-lived assets, net	4.8		186.9
Gain on acquisition	—		(75.3)
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	(133.3)		(0.9)
Deferred income taxes	(0.1)		1.1
Other	0.1		—
Changes in operating assets and liabilities	30.5		(123.9)
Net cash provided by operating activities	378.5		277.3
Investing activities
Acquisitions, net of cash acquired (Note 3)	—		(604.3)
Purchases of property, plant and equipment	(164.0)		(147.3)
Investments in unconsolidated affiliates	(7.2)		(90.2)
Capital distributions from unconsolidated affiliates	4.4		9.4
Net proceeds from sale of assets, including equity investments	188.2		315.2
Net cash provided by (used in) investing activities	21.4		(517.2)
Financing activities
Proceeds from the issuance of long-term debt	2,058.3		3,072.0
Payments on long-term debt	(2,127.4)		(2,393.1)
Payments on finance leases	(2.0)		(31.3)
Payments for deferred financing costs	(9.2)		(1.8)
Purchase of common units	—		(123.7)
Distributions to partners	(206.7)		(196.7)
Distributions to non-controlling partner	(31.0)		(31.0)
Distributions to preferred unitholders	(45.1)		(45.0)
Taxes paid for unit-based compensation vesting	(20.5)		(15.8)
Other	—		(0.6)
Net cash provided by (used in) financing activities	(383.6)		233.0
Net change in cash	16.3		(6.9)
Cash at beginning of period	7.5		13.3
Cash at end of period	$	23.8	$	6.4
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$	(18.4)	$	19.9

See accompanying notes.

8

CRESTWOOD MIDSTREAM PARTNERS LP

CONSOLIDATED BALANCE SHEETS

(in millions)

	September 30, 2023		December 31, 2022
	(unaudited)
Assets
Current assets:
Cash	$	23.4	$	7.1
Accounts receivable, less allowance for doubtful accounts of $0.5      at both September 30, 2023 and December 31, 2022	350.0		432.2
Inventory	179.9		122.6
Assets from price risk management activities	38.0		72.8
Prepaid expenses and other current assets	8.5		18.7
Total current assets	599.8		653.4
Property, plant and equipment	5,464.3		5,350.0
Less: accumulated depreciation	999.3		822.6
Property, plant and equipment, net	4,465.0		4,527.4
Intangible assets	1,234.6		1,306.3
Less: accumulated amortization	277.9		300.7
Intangible assets, net	956.7		1,005.6
Goodwill	223.0		223.0
Operating lease right-of-use assets, net	23.3		24.4
Investments in unconsolidated affiliates	77.1		119.5
Other non-current assets	9.3		8.1
Total assets	$	6,354.2	$	6,561.4
Liabilities and capital
Current liabilities:
Accounts payable	$	256.9	$	305.4
Accrued expenses and other liabilities	182.7		179.5
Liabilities from price risk management activities	17.6		23.9
Total current liabilities	457.2		508.8
Long-term debt, less current portion	3,302.5		3,378.3
Other long-term liabilities	321.3		330.3
Deferred income taxes	2.5		2.3
Total liabilities	4,083.5		4,219.7
Commitments and contingencies (Note 9)
Interest of non-controlling partner in subsidiary	456.0		434.4
Partners’ capital	1,814.7		1,907.3
Total liabilities and capital	$	6,354.2	$	6,561.4

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,
	2023		2022		2023		2022
Revenues:
Product revenues	$	989.2	$	1,332.8	$	2,991.5	$	3,938.3
Product revenues - related party (Note 15)	—		83.2		—		222.7
Service revenues	150.2		92.4		432.2		286.8
Service revenues - related party (Note 15)	—		57.6		—		150.0
Total revenues	1,139.4		1,566.0		3,423.7		4,597.8
Costs of product/services sold (exclusive of items shown separately below):
Product costs	898.1		1,228.6		2,668.1		3,613.4
Product costs - related party (Note 15)	—		51.3		0.5		232.9
Service costs	3.5		6.9		15.0		18.1
Total costs of product/services sold	901.6		1,286.8		2,683.6		3,864.4
Operating expenses and other:
Operations and maintenance	56.9		55.0		166.7		144.0
General and administrative	20.8		32.3		74.6		99.0
Depreciation, amortization and accretion	80.1		86.8		242.5		248.0
Loss on long-lived assets, net	2.6		247.6		4.8		311.9
Gain on acquisition	—		(75.3)		—		(75.3)
	160.4		346.4		488.6		727.6
Operating income (loss)	77.4		(67.2)		251.5		5.8
Earnings from unconsolidated affiliates, net	1.1		3.2		135.2		12.2
Interest and debt expense, net	(56.9)		(47.6)		(167.9)		(123.8)
Income (loss) before income taxes	21.6		(111.6)		218.8		(105.8)
Provision for income taxes	(0.2)		(1.4)		(1.0)		(1.6)
Net income (loss)	21.4		(113.0)		217.8		(107.4)
Net income attributable to non-controlling partner	32.1		10.3		52.6		30.8
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(10.7)	$	(123.3)	$	165.2	$	(138.2)

See accompanying notes.

10

CRESTWOOD MIDSTREAM PARTNERS LP

CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL

(in millions)

(unaudited)

	Total Partners’ Capital
Balance at December 31, 2022	$	1,907.3
Distributions to partners	(85.9)
Unit-based compensation	11.8
Taxes paid for unit-based compensation vesting	(14.8)
Net income	32.8
Balance at March 31, 2023	$	1,851.2
Distributions to partners	(85.4)
Unit-based compensation	9.2
Taxes paid for unit-based compensation vesting	(0.8)
Net income	143.1
Balance at June 30, 2023	$	1,917.3
Distributions to partners	(93.5)
Unit-based compensation	6.5
Taxes paid for unit-based compensation vesting	(4.9)
Net loss	(10.7)
Balance at September 30, 2023	$	1,814.7

	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	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	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	8.0
Taxes paid for unit-based compensation vesting	(0.2)
Net loss	(123.3)
Balance at September 30, 2022	$	1,937.1

See accompanying notes.

11

CRESTWOOD MIDSTREAM PARTNERS LP

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)

(unaudited)

	Nine Months Ended
	September 30,
	2023		2022
Operating activities
Net income (loss)	$	217.8	$	(107.4)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	242.5		248.0
Amortization of debt-related deferred costs and fair value adjustment	2.5		1.7
Unit-based compensation	25.7		26.8
Loss on long-lived assets, net	4.8		311.9
Gain on acquisition	—		(75.3)
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	(133.3)		(0.9)
Deferred income taxes	0.2		1.2
Other	0.1		—
Changes in operating assets and liabilities	31.2		(123.9)
Net cash provided by operating activities	391.5		282.1
Investing activities
Acquisitions, net of cash acquired (Note 3)	—		(602.7)
Purchases of property, plant and equipment	(164.0)		(146.6)
Investments in unconsolidated affiliates	(7.2)		(90.2)
Capital distributions from unconsolidated affiliates	4.4		9.4
Net proceeds from sale of assets, including equity investments	188.2		315.2
Net cash provided by (used in) investing activities	21.4		(514.9)
Financing activities
Proceeds from the issuance of long-term debt	2,058.3		3,072.0
Payments on long-term debt	(2,127.4)		(2,393.1)
Payments on finance leases	(2.0)		(31.3)
Payments for deferred financing costs	(9.2)		(1.8)
Contributions from partner	—		164.3
Distributions to partners	(264.8)		(537.6)
Distributions to non-controlling partner	(31.0)		(31.0)
Taxes paid for unit-based compensation vesting	(20.5)		(15.8)
Net cash provided by (used in) financing activities	(396.6)		225.7
Net change in cash	16.3		(7.1)
Cash at beginning of period	7.1		12.9
Cash at end of period	$	23.4	$	5.8
Supplemental schedule of non-cash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$	(18.4)	$	19.9

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).

The accompanying consolidated financial statements and related notes should be read in conjunction with our 2022 Annual Report on Form 10-K filed with the Securities and Exchange Commission (SEC) on February 27, 2023. The financial information as of September 30, 2023 and for the three and nine months ended September 30, 2023 and 2022, is unaudited. The consolidated balance sheets as of December 31, 2022 were derived from the audited balance sheets filed in our 2022 Annual Report on Form 10-K.

Unless otherwise indicated, references in this report to “we,” “us,” “our,” “ours,” “our company,” the “Partnership,” the “Company,” “Crestwood Equity,” “CEQP,” and similar terms refer to either Crestwood Equity Partners LP itself or Crestwood Equity Partners LP and its consolidated subsidiaries, as the context requires. Unless otherwise indicated, references to “Crestwood Midstream” and “CMLP” refer to Crestwood Midstream Partners LP and its consolidated subsidiaries, as the context requires.

Organization

Energy Transfer LP Merger. On November 3, 2023, Crestwood Equity is expected to merge with and into a direct wholly-owned subsidiary of Energy Transfer LP (Energy Transfer) in an all-equity transaction valued at approximately $7.1 billion (the Energy Transfer Merger). On August 16, 2023, Crestwood Equity entered into a merger agreement with Energy Transfer pursuant to which each Crestwood Equity common unit representing limited partner interests in Crestwood Equity issued and outstanding immediately prior to the Energy Transfer Merger will be converted into the right to receive 2.07 common units representing limited partner interests in Energy Transfer. Each preferred unit representing limited partner interests in Crestwood Equity issued and outstanding immediately prior to the Energy Transfer Merger will, at the election of the holder of such preferred unit, be (i) converted into a preferred unit of Energy Transfer that has substantially similar terms, including with respect to economics and structural protections, as the preferred units of Crestwood Equity, (ii) redeemed in exchange for cash, at a price of 108% of the preferred unit price plus accrued and unpaid distributions to the date of such redemption, or (iii) converted into common units, at the then-applicable conversion ratio (one common unit for 10 preferred), subject to the payment of any accrued but unpaid distributions prior to Energy Transfer Merger. In connection with the Energy Transfer Merger and at the direction of Energy Transfer, Crestwood Equity conducted a consent solicitation pursuant to which Crestwood Equity solicited consent from the preferred unitholders to approve an amendment to its Sixth Amended and Restated Agreement of Limited Partnership. Pursuant to the proposed amendment, among other things, (i) the preferred unitholders electing a cash redemption in the Energy Transfer Merger would receive such cash redemption price as increased from 101% to 108% of the preferred unit price; and (ii) the preferred unitholders electing to receive preferred units of Energy Transfer would receive such preferred units of Energy Transfer with terms similar to Energy Transfer’s other outstanding series of preferred units. Crestwood Equity received the consents from the preferred unitholders necessary to approve the proposed amendment and therefore, the proposed amendment will be adopted at the closing of the Energy Transfer Merger.

For more information regarding the merger and the merger agreement, see our Current Report on Form 8-K filed with the SEC on August 16, 2023 and our definitive merger proxy statement on Schedule 14A filed with the SEC on September 29, 2023.

Crestwood Equity Partners LP. CEQP is a publicly-traded Delaware limited partnership, and its common units are listed on the New York Stock Exchange (NYSE) under the ticker symbol “CEQP” and its preferred units are listed on the NYSE under the ticker symbol “CEQP-P.” In connection with the consummation of the Energy Transfer Merger, we requested that the NYSE delist our common and preferred units and, as a result, trading of our common and preferred units will be suspended on November 3, 2023. We also requested that the NYSE file a Form 25 with the SEC notifying the SEC of the delisting of our common and preferred units and the withdrawal of registration of our common and preferred units under Section 12(b) of the Exchange Act. Following the effectiveness of the Form 25, we intend to file with the SEC a Form 15 regarding the termination of registration of our common and preferred units under the Exchange Act and the suspension of reporting obligations with respect to our common and preferred units.

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Crestwood Midstream Partners LP. Crestwood Equity owns a 99.9% limited partnership interest in Crestwood Midstream and Crestwood Gas Services GP LLC, 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 North America. 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 in the United States (U.S. 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 U.S. 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 2022 Annual Report on Form 10-K.

Note 3 – Acquisitions and Divestitures

Oasis Merger

On February 1, 2022, we completed the merger with Oasis Midstream Partners LP (Oasis Midstream), in an equity and cash transaction which was valued at approximately $1.8 billion (the Oasis Merger). Pursuant to the merger agreement, Oasis Petroleum Inc., now known as Chord Energy Corporation (Chord), 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, Chord received a $10 million cash payment in exchange for its ownership of the general partner of Oasis Midstream.

Sendero and CPJV Acquisitions

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). Additionally, 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). 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. Prior to the CPJV Acquisition, we owned a 50% equity interest in Crestwood Permian, which we accounted for under the equity method of

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accounting and we reflected this equity investment in our gathering and processing south segment. As a result of the CPJV Acquisition, we control and own 100% of the equity interests in Crestwood Permian.

Divestitures

Barnett

On July 1, 2022, we sold our assets in the Barnett Shale to EnLink Midstream, LLC for approximately $290 million, and during the nine months ended September 30, 2022, Crestwood Midstream recorded a loss on the sale of approximately $53.3 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 our 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 loss on long-lived assets, net on its consolidated statements of operations.

Marcellus

In October 2022, we sold our assets in the Marcellus Shale to Antero Midstream Corporation for approximately $206 million, and during the three months ended September 30, 2022, we recorded a loss on long-lived assets of approximately $248.2 million for the difference between the historical carrying value of the net assets and liabilities to be sold and the proceeds received from the sale.

Other Divestitures

In August 2023, we sold our transportation assets for approximately $8.0 million, and during the three months ended September 30, 2023, we recorded a loss on long-lived assets of approximately $2.5 million related to the sale of these assets. During the nine months ended September 30, 2022, we recorded a loss on long-lived assets of approximately $7.0 million related to the sale of parts inventory related to our legacy Granite Wash operations.

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,
	2023		2022
CMLP
Accrued expenses	$	56.9	$	66.5
Accrued property taxes	10.5		8.4
Income tax payable	0.7		0.9
Interest payable	64.4		43.2
Accrued additions to property, plant and equipment	16.3		35.6
Operating leases	11.1		10.9
Finance leases	1.7		1.9
Contract liabilities	20.3		11.7
Asset retirement obligations	0.8		0.4
Total CMLP accrued expenses and other liabilities	$	182.7	$	179.5
CEQP
Accrued expenses	0.9		1.2
Income tax payable	—		0.1
Total CEQP accrued expenses and other liabilities	$	183.6	$	180.8

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Other Long-Term Liabilities

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

	September 30,		December 31,
	2023		2022
CMLP
Contract liabilities	$	207.4	$	212.3
Intangible liabilities, net	45.5		50.0
Asset retirement obligations	38.5		36.4
Operating leases	15.4		17.4
Other	14.5		14.2
Total CMLP other long-term liabilities	$	321.3	$	330.3
CEQP
Other	2.1		3.1
Total CEQP other long-term liabilities	$	323.4	$	333.4

Note 5 - Investments in Unconsolidated Affiliates

Tres Holdings Divestiture

On February 20, 2023, we and Brookfield Infrastructure Group (Brookfield) entered into an agreement with a subsidiary of Enbridge, Inc. to sell each of our respective interests in Tres Palacios Holdings LLC (Tres Holdings) for approximately $335 million, plus working capital adjustments. The sale was completed on April 3, 2023 and we received net cash proceeds of approximately $178 million. We recorded a gain on the sale of approximately $132 million, which is reflected as an increase in our earnings from unconsolidated affiliates in our consolidated statements of operations during the nine months ended September 30, 2023.

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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,
	2023		2022		2023		2022		2023		2022
Crestwood Permian Basin LLC(1)	$	74.0	$	76.5	$	1.1	$	0.7	$	2.0	$	0.7
Tres Palacios Holdings LLC(2)	—		39.8		0.1		1.3		133.6		3.2
Powder River Basin Industrial Complex, LLC(3)	3.1		3.2		(0.1)		(0.1)		(0.4)		(0.4)
Crestwood Permian Basin Holdings LLC(4)	—		—		—		1.3		—		8.7
Total	$	77.1	$	119.5	$	1.1	$	3.2	$	135.2	$	12.2

(1)As discussed in Note 3, in July 2022, we acquired the remaining 50% equity interest in Crestwood Permian, whose operations included its 50% equity interest in Crestwood Permian Basin LLC (Crestwood Permian Basin). As of September 30, 2023, our equity in the underlying net assets of Crestwood Permian Basin was less than the carrying value of our investment balance by approximately $2.2 million. During the three and nine months ended September 30, 2023, we recorded amortization of less than $0.1 million and approximately $0.1 million, respectively, related to this basis difference, which is reflected as a decrease in our earnings from unconsolidated affiliates in our consolidated statements of operations, and during both the three and nine months ended September 30, 2022, we recorded amortization of less than $0.1 million related to this basis difference. Our Crestwood Permian Basin investment is included in our gathering and processing south segment.

(2)In April 2023, we sold our equity interest in Tres Holdings and we recorded a gain on the sale of approximately $132 million, which eliminated our $19.9 million historical basis difference between our investment balance and our equity in the underlying net assets of Tres Holdings. During the nine months ended September 30, 2023, we recorded amortization of approximately $0.3 million related to this excess basis, which is reflected as an increase in our earnings from unconsolidated affiliates in our consolidated statements of operations, and during the three and nine months ended September 30, 2022, we recorded amortization of approximately $0.3 million and $0.9 million related to this excess basis. Our Tres Holdings investment was included in our storage and logistics segment. See Tres Holdings Divestiture above for a further discussion of the sale of our Tres Holdings equity investment.

(3)As of September 30, 2023, our equity in the underlying net assets of Powder River Basin Industrial Complex, LLC (PRBIC) approximates the carrying value of our investment balance. Our PRBIC investment is included in our storage and logistics segment.

(4)In July 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. Our Crestwood Permian equity investment was previously included in our gathering and processing south segment. See Note 3 for a further discussion of this acquisition.

Distributions and Contributions

The following table summarizes our distributions from and contributions to our unconsolidated affiliates (in millions):

	Distributions				Contributions
	Nine Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Crestwood Permian Basin	$	6.3	$	2.2	$	1.8	$	—
Tres Holdings	—		4.9		5.1		6.7
PRBIC	—		—		0.3		—
Crestwood Permian	—		13.6		—		83.5
Total	$	6.3	$	20.7	$	7.2	$	90.2

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

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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. Our commodity-based derivatives that are settled financially are also reflected in product costs in our consolidated statements of operations. The following table summarizes the increase (decrease) in our product revenues and product costs, net, in our consolidated statements of operations related to our commodity-based derivatives (in millions):

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Product revenues	$	49.1	$	84.7	$	236.0	$	395.7
Product costs, net	$	18.0	$	(45.0)	$	(13.5)	$	6.3

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, 2023		December 31, 2022
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, ethane, butane, heating oil and crude oil (MMBbls)	72.9	78.7	67.2	70.2
Natural gas (Bcf)	11.3	12.8	44.2	48.4

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. 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. For a summary of the fair value of our commodity derivative instruments with credit-risk related contingent features and their associated collateral, see Note 7.

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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 — Includes inputs that are observable in active markets for identical assets or liabilities as of the reporting date such as exchange-traded derivatives, listed equities and U.S. government treasury securities.

•Level 2 — Includes inputs that are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Instruments in this category include non-exchange-traded derivatives such as over the counter (OTC) forwards, options and physical exchanges.

•Level 3 — Includes 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, 2023 and December 31, 2022, 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 have been categorized as Level 2.

The following tables summarize the fair value hierarchy of our financial instruments that were reflected in our consolidated balance sheets (in millions):

	September 30, 2023
	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	$	14.5	$	248.6	$	—	$	263.1	$	(213.9)	$	(11.2)	$	38.0
Other investments(2)	2.8		—		—		2.8		—		—		2.8
Total assets at fair value	$	17.3	$	248.6	$	—	$	265.9	$	(213.9)	$	(11.2)	$	40.8
Liabilities
Liabilities from price risk management with credit-risk-related contingent features	$	11.5	$	206.2	$	—	$	217.7	$	(213.9)	$	3.9	$	7.7
Liabilities from price risk management without credit-risk-related contingent features	—		5.5		—		5.5		—		4.4		9.9
Total liabilities at fair value	$	11.5	$	211.7	$	—	$	223.2	$	(213.9)	$	8.3	$	17.6

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	December 31, 2022
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting(1)		Collateral/Margin Received or Paid		Fair Value
Assets
Assets from price risk management	$	62.8	$	474.3	$	—	$	537.1	$	(452.1)	$	(12.2)	$	72.8
Other investments(2)	2.6		—		—		2.6		—		—		2.6
Total assets at fair value	$	65.4	$	474.3	$	—	$	539.7	$	(452.1)	$	(12.2)	$	75.4
Liabilities
Liabilities from price risk management with credit-risk-related contingent features	$	65.7	$	420.1	$	—	$	485.8	$	(452.1)	$	(25.6)	$	8.1
Liabilities from price risk management without credit-risk-related contingent features	—		11.9		—		11.9		—		3.9		15.8
Total liabilities at fair value	$	65.7	$	432.0	$	—	$	497.7	$	(452.1)	$	(21.7)	$	23.9

(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, 2023 and December 31, 2022, 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, 2023 and December 31, 2022, primarily due 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, 2023				December 31, 2022
	Carrying  Amount		Fair Value		Carrying  Amount		Fair Value
2025 Senior Notes	$	498.4	$	491.8	$	497.6	$	486.7
2027 Senior Notes	$	596.1	$	576.7	$	595.3	$	556.9
February 2029 Senior Notes	$	693.1	$	674.4	$	692.1	$	642.1
April 2029 Senior Notes(1)	$	473.5	$	464.2	$	476.7	$	450.0
2031 Senior Notes	$	591.6	$	611.5	$	—	$	—

(1)    The carrying amount includes a fair value adjustment we recorded in conjunction with the merger with Oasis Midstream discussed in Note 3. For a further discussion of this fair value adjustment, see Note 8.

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Note 8 – Long-Term Debt

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

	September 30, 2023		December 31, 2022
CMLP Credit Facility	$	460.0	$	922.3
CPBH Credit Facility	—		206.8
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		450.0
April 2029 Senior Notes fair value adjustment, net(1)	23.5		26.7
2031 Senior Notes	600.0		—
Less: deferred financing costs, net	31.0		27.5
Total long-term debt	$	3,302.5	$	3,378.3

(1)In conjunction with the merger with Oasis Midstream discussed in Note 3, we assumed the April 2029 Senior Notes, and we recorded a fair value adjustment of approximately $30.7 million. We recorded a reduction to our interest and debt expense related to the amortization of the fair value adjustment of approximately $1.1 million and $3.2 million during the three and nine months ended September 30, 2023 and $1.1 million and $2.9 million during the three and nine months ended September 30, 2022.

Credit Facilities

CMLP Credit Facility. Crestwood Midstream’s five-year $1.75 billion revolving credit facility (the CMLP Credit Facility) is available to fund acquisitions, working capital and internal growth projects and for general partnership purposes. Subject to limited exception, the CMLP Credit Facility is guaranteed and secured by substantially all of the equity interests and assets of Crestwood Midstream’s subsidiaries, except for Crestwood Infrastructure Holdings LLC, Crestwood Niobrara LLC, PRBIC and their respective subsidiaries. In January 2023, Crestwood Permian and certain of its subsidiaries were designated as guarantor subsidiaries of Crestwood Midstream’s credit facility and senior notes.

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, in July 2022 we borrowed approximately $631.2 million under the CMLP Credit Facility to fund the Sendero Acquisition.

Under the credit agreement, Crestwood Midstream is required to maintain a net debt to consolidated EBITDA ratio (as defined in the credit agreement) of not more than 5.50 to 1.0, a consolidated EBITDA to consolidated interest expense ratio (as defined in the credit agreement) of not less than 2.50 to 1.0, and a senior secured leverage ratio (as defined in the credit agreement) of not more than 3.50 to 1.0. At September 30, 2023, the net debt to consolidated EBITDA ratio was approximately 4.35 to 1.0, the consolidated EBITDA to consolidated interest expense ratio was approximately 3.65 to 1.0, and the senior secured leverage ratio was 0.61 to 1.0.

At September 30, 2023, Crestwood Midstream had $872.0 million of available capacity under the CMLP Credit Facility considering the most restrictive debt covenants in the credit agreement. At September 30, 2023 and December 31, 2022, outstanding standby letters of credit under the CMLP Credit Facility were $5.7 million and $8.2 million. Borrowings under the CMLP 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 7.67% and 9.75% at September 30, 2023 and 6.28% and 8.50% at December 31, 2022. The weighted-average interest rate on outstanding borrowings as of September 30, 2023 and December 31, 2022 was 7.68% and 6.40%.

CPBH Credit Facility. In conjunction with the acquisition of the remaining 50% equity interest in Crestwood Permian in July 2022, we assumed a credit agreement entered into by CPB Subsidiary Holdings LLC, a wholly-owned subsidiary of Crestwood Permian (the CPBH Credit Facility). In January 2023, we utilized borrowings under the CMLP Credit Facility to repay and terminate the CPBH Credit Facility.

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Senior Notes

2031 Senior Notes. In January 2023, Crestwood Midstream issued $600 million of 7.375% unsecured senior notes due 2031 (the 2031 Senior Notes). The 2031 Senior Notes will mature on February 1, 2031, and interest is payable semi-annually in arrears on February 1 and August 1 of each year, beginning on August 1, 2023. The net proceeds from this offering of approximately $592.5 million were used to repay borrowings outstanding 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.

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, 2023. On January 9, 2023, we paid approximately $21.2 million to the Court Registry under protest to mitigate the impact of post-judgement interest. We filed a Notice of Appeal on January 13, 2023 and an Opening Appeal Brief on September 29, 2023. We are unable to predict the ultimate outcome of the appeal related to 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, 2023 and December 31, 2022, we had approximately $8.9 million and $35.0 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 both September 30, 2023 and December 31, 2022, our accrual for environmental matters was less than $1.0 million and our potential exposure related to environmental matters was less than $1.0 million at September 30, 2023.

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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, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Self-insurance reserves(1)	$	5.7	$	5.6	$	5.0	$	4.8

(1)At September 30, 2023, CEQP and CMLP classified approximately $3.2 million and $2.7 million, respectively, of these reserves as other long-term liabilities on their consolidated balance sheets.

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, 2023 and December 31, 2022, 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, 2023		December 31, 2022
Operating Leases
Operating lease right-of-use assets, net	$	23.3	$	24.4
Accrued expenses and other liabilities	$	11.1	$	10.9
Other long-term liabilities	15.4		17.4
Total operating lease liabilities	$	26.5	$	28.3
Finance Leases
Property, plant and equipment	$	9.8	$	13.6
Less: accumulated depreciation	4.9		8.9
Property, plant and equipment, net	$	4.9	$	4.7
Accrued expenses and other liabilities	$	1.7	$	1.9
Other long-term liabilities	3.0		2.7
Total finance lease liabilities	$	4.7	$	4.6

Lease expense. Our operating lease expense, net totaled $3.5 million and $3.4 million for the three months ended September 30, 2023 and 2022 and $10.9 million and $9.2 million for the nine months ended September 30, 2023 and 2022. Our finance lease expense totaled $0.6 million and $0.9 million for the three months ended September 30, 2023 and 2022 and $2.1 million and $2.7 million for the nine months ended September 30, 2023 and 2022.

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Other. During March 2022, we exercised an option to purchase crude oil railcars under certain of our finance 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 Units

On February 1, 2022, we completed the merger with Oasis Midstream. Pursuant to the merger agreement, Chord 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 Reserves’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, for approximately $123.7 million. This transaction resulted in CEQP retiring the common units acquired from OMS Holdings LLC.

Distributions

Crestwood Equity

Limited Partners. A summary of CEQP’s limited partner quarterly cash distributions for the nine months ended September 30, 2023 and 2022 is presented below:

Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2023
February 7, 2023	February 14, 2023	$	0.655	$	68.9
May 8, 2023	May 15, 2023	$	0.655	68.9
August 7, 2023	August 14, 2023	$	0.655	68.9
				$	206.7
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

On October 12, 2023, the board of directors of our general partner declared a cash distribution of $0.655 per limited partner unit with respect to the quarter ended September 30, 2023. In addition, the board of directors declared a special cash distribution of $0.003 per limited partner unit in conjunction with the Energy Transfer Merger. The cash distributions were paid on October 31, 2023 to unitholders of record on October 23, 2023.

Preferred Unitholders. During the nine months ended September 30, 2023 and 2022, we paid cash distributions of approximately $45.1 million and $45.0 million to our preferred unitholders. On October 12, 2023, the board of directors of our general partner declared a cash distribution of approximately $15 million with respect to the quarter ended September 30, 2023. In addition, the board of directors declared a special cash distribution of $0.0003 per preferred unit in conjunction with the Energy Transfer Merger. The cash distributions were paid on October 31, 2023 to unitholders of record on October 23, 2023.

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Crestwood Midstream

During the nine months ended September 30, 2023 and 2022, Crestwood Midstream paid cash distributions of $264.8 million and $537.6 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, Crestwood Equity contributed the 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, Crestwood Equity contributed the 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 LLC (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 liquidation value each period through net income attributable to non-controlling partner.

In July 2023, we entered into a Fourth Amended and Restated Limited Liability Company Agreement with Jackalope Holdings to modify certain provisions related to the conversion and redemption of the Crestwood Niobrara preferred units. In conjunction with the merger agreement we entered into with Energy Transfer in August 2023 which is further discussed in Note 1, the Crestwood Niobrara preferred units became currently redeemable and as a result, we reflected the Crestwood Niobrara preferred units at their Change of Control Redemption Price (as defined in the agreement) which is equal to 105% of the liquidation value.

The following tables show the change in our non-controlling interest in subsidiary at September 30, 2023 and 2022 (in millions):

Balance at December 31, 2022	$	434.4
Distributions to non-controlling partner	(31.0)
Net income attributable to non-controlling partner(1)	52.6
Balance at September 30, 2023	$	456.0

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

(1)Includes approximately $21.7 million recorded during the three months ended September 30, 2023 to reflect the Crestwood Niobrara preferred units at their maximum redemption value as discussed above.

In October 2023, Crestwood Niobrara paid a cash distribution of approximately $10.3 million to Jackalope Holdings with respect to the quarter ended September 30, 2023.

Other

In February 2023, Crestwood Equity issued 245,929 performance units (the February 2023 Units) under the Crestwood Equity Partners LP 2018 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, 2023, we had total unamortized compensation expense

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of approximately $4.5 million related to the February 2023 Units. During the three and nine months ended September 30, 2023, we recognized compensation expense of $0.5 million and $1.9 million related to the February 2023 Units, which is included in general and administrative expenses on our consolidated statements of operations.

During the nine months ended September 30, 2023, 161,278 performance units that were previously issued in 2020 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 217,702 common units during the nine months ended September 30, 2023 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 unit-based compensation performance units is calculated using the treasury stock method which considers the impact to net income or loss attributable to Crestwood Equity Partners and limited partner units from the potential issuance of limited partner units.

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, 2023 and 2022 (in millions):

	Three Months Ended		Nine Months Ended
	September 30,		September 30,
	2023	2022	2023	2022
Preferred units(1)	7.1	7.1	7.1	7.1
Crestwood Niobrara’s preferred units(1)	3.8	3.9	—	3.9
Unit-based compensation performance units(1)	0.1	0.1	—	0.2

(1)For additional information regarding the potential conversion/redemption of our preferred units and Crestwood Niobrara’s preferred units to CEQP common units, and additional information regarding our performance units, see our 2022 Annual Report on Form 10-K, Note 1 and Note 11.

The following table shows Crestwood Equity’s common unitholders’ interest in net income (loss) and weighted-average limited partner units used in computing basic and diluted net income (loss) per limited partner unit for the three and nine months ended September 30, 2023 and 2022 (in millions, except for per unit data):

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Common unitholders’ interest in net income (loss)	$	(35.1)	$	(68.3)	$	107.9	$	(57.2)
Diluted net income (loss)	$	(35.1)	$	(68.3)	$	107.9	$	(57.2)
Weighted-average limited partners’ units outstanding - basic	105.2		107.1		105.2		97.1
Dilutive effect of Crestwood Niobrara preferred units	—		—		3.8		—
Dilutive effect of unit-based compensation performance units	—		—		0.1		—
Weighted-average limited partners’ units outstanding - diluted	105.2		107.1		109.1		97.1
Net income (loss) per limited partner unit:
Basic	$	(0.33)	$	(0.64)	$	1.03	$	(0.59)
Diluted	$	(0.33)	$	(0.64)	$	0.99	$	(0.59)

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Note 13 – Segments

Our financial statements reflect three operating and reporting segments: (i) gathering and processing north operations; (ii) gathering and processing south operations; and (iii) storage and logistics operations. 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, crude oil gathering services and produced water gathering and disposal services to producers in the Delaware Basin.

•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.

We assess the performance of our operating segments based on EBITDA, which is identified as income (loss) before debt-related costs (interest and debt expense, net), income taxes and depreciation, amortization and accretion expense. Below is a reconciliation of CEQP’s and CMLP’s net income 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,
	2023		2022		2023		2022		2023		2022		2023		2022
Net income (loss)	$	12.1	$	(43.0)	$	205.6	$	18.6	$	21.4	$	(113.0)	$	217.8	$	(107.4)
Add:
Interest and debt expense, net	56.9		47.6		167.9		123.8		56.9		47.6		167.9		123.8
Provision for income taxes	0.2		1.4		1.1		1.7		0.2		1.4		1.0		1.6
Depreciation, amortization and accretion	80.2		86.9		242.7		242.3		80.1		86.8		242.5		248.0
EBITDA	$	149.4	$	92.9	$	617.3	$	386.4	$	158.6	$	22.8	$	629.2	$	266.0

The following tables summarize CEQP’s and CMLP’s reportable segment data for the three and nine months ended September 30, 2023 and 2022 (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 2022 Annual Report on Form 10-K. Included in earnings from unconsolidated affiliates, net reflected in the tables below was approximately $1.3 million and $2.5 million of our proportionate share of net interest income, income taxes, depreciation and amortization expense and gains on long-lived assets, net recorded by our equity investments for the three months ended September 30, 2023 and 2022 and $5.4 million and $12.0 million for the nine months ended September 30, 2023 and 2022.

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Segment EBITDA Information

	Three Months Ended September 30, 2023
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	262.8	$	123.0	$	753.6	$	—	$	1,139.4
Intersegment revenues, net	70.9		52.5		(123.4)		—		—
Costs of product/services sold	158.4		121.1		622.1		—		901.6
Operations and maintenance expense	29.9		14.9		12.1		—		56.9
General and administrative expense	—		—		—		20.8		20.8
Loss on long-lived assets, net	—		—		(2.6)		—		(2.6)
Earnings from unconsolidated affiliates, net	—		1.1		—		—		1.1
Crestwood Midstream EBITDA	$	145.4	$	40.6	$	(6.6)	$	(20.8)	$	158.6
Crestwood Equity
General and administrative expense	—		—		—		9.4		9.4
Other income, net	—		—		—		0.2		0.2
Crestwood Equity EBITDA	$	145.4	$	40.6	$	(6.6)	$	(30.0)	$	149.4

	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(1)	—		71.7		—		—		71.7
Crestwood Equity EBITDA	$	157.2	$	(47.3)	$	16.9	$	(33.9)	$	92.9

(1)Represents the gain on the sale of our Barnett operations recorded by CEQP. For a further discussion of this transaction, see Note 3.

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	Nine Months Ended September 30, 2023
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	717.1	$	373.3	$	2,333.3	$	—	$	3,423.7
Intersegment revenues, net	231.0		119.2		(350.2)		—		—
Costs of product/services sold	447.7		329.8		1,906.1		—		2,683.6
Operations and maintenance expense	85.6		45.2		35.9		—		166.7
General and administrative expense	—		—		—		74.6		74.6
Gain (loss) on long-lived assets, net	0.1		(2.7)		(2.6)		0.4		(4.8)
Earnings from unconsolidated affiliates, net(1)	—		2.0		133.2		—		135.2
Crestwood Midstream EBITDA	$	414.9	$	116.8	$	171.7	$	(74.2)	$	629.2
Crestwood Equity
General and administrative expense	—		—		—		12.2		12.2
Other income, net	—		—		—		0.3		0.3
Crestwood Equity EBITDA	$	414.9	$	116.8	$	171.7	$	(86.1)	$	617.3

(1)In April 2023, we sold our equity interest in Tres Holdings which is reflected in our storage and logistics segment. During the nine months ended September 30, 2023, we recorded a gain on the sale of approximately $132 million, which is reflected as an increase in our earnings from unconsolidated affiliates.

	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 legacy assets in the Barnett Shale and a gain on long-lived assets of approximately $72 million recorded by CEQP related to the sale. For a further discussion of this transaction, see Note 3.

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Other Segment Information

	CEQP				CMLP
	September 30, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Total Assets
Gathering and Processing North	$	3,921.3	$	4,003.6	$	3,921.3	$	4,003.6
Gathering and Processing South	1,452.4		1,473.0		1,452.4		1,473.0
Storage and Logistics	946.1		1,057.6		946.1		1,057.6
Corporate	40.0		32.8		34.4		27.2
Total assets	$	6,359.8	$	6,567.0	$	6,354.2	$	6,561.4

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 Accounting Standards Update 2014-09, Revenue from Contracts with Customers (Topic 606) totaled $336.5 million and $368.2 million at September 30, 2023 and December 31, 2022, 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 14 years.

The following table summarizes our contract assets and contract liabilities (in millions):

	September 30, 2023		December 31, 2022
Contract assets (non-current)	$	6.8	$	5.4
Contract liabilities (current)(1)	$	20.3	$	11.7
Contract liabilities (non-current)(1)	$	207.4	$	212.3

(1)During the three and nine months ended September 30, 2023, we recognized revenues of approximately $4.5 million and $14.9 million that were previously included in contract liabilities at December 31, 2022. The remaining change in our contract liabilities during the three and nine months ended September 30, 2023 is 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, 2023 (in millions):

Remainder of 2023	$	16.5
2024	46.4
2025	6.5
2026	4.9
2027	2.1
Thereafter	1.1
Total	$	77.5

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.

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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, 2023 and 2022 (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, 2023
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	32.2	$	4.8	$	—	$	—	$	37.0
Crude oil	16.9		1.9		—		—		18.8
Water	51.0		8.4		—		—		59.4
Processing
Natural gas	20.0		6.9		—		—		26.9
Storage
Crude oil	0.6		—		—		—		0.6
NGLs	—		—		2.1		—		2.1
Pipeline
Crude oil	1.4		0.1		0.6		—		2.1
NGLs	—		6.8		0.2		(6.8)		0.2
Transportation
NGLs	—		—		2.2		—		2.2
Rail Loading
Crude oil	—		—		0.2		—		0.2
Product Sales
Natural gas	27.4		47.5		78.2		(70.1)		83.0
Crude oil	139.4		0.8		352.2		(15.0)		477.4
NGLs	42.8		98.8		268.4		(31.3)		378.7
Water	1.0		—		—		—		1.0
Other	0.5		—		0.1		(0.2)		0.4
Total Topic 606 revenues	333.2		176.0		704.2		(123.4)		1,090.0
Non-Topic 606 revenues	0.5		(0.5)		49.4		—		49.4
Total revenues	$	333.7	$	175.5	$	753.6	$	(123.4)	$	1,139.4

31

	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	1.5		0.1		0.6		—		2.2
NGLs	—		5.2		0.1		(5.2)		0.1
Transportation
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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	Nine Months Ended September 30, 2023
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	95.5	$	13.6	$	—	$	—	$	109.1
Crude oil	46.3		6.0		—		—		52.3
Water	139.9		25.2		—		—		165.1
Processing
Natural gas	56.6		19.6		—		—		76.2
Storage
Crude oil	1.7		—		0.1		(0.2)		1.6
NGLs	—		—		6.4		—		6.4
Pipeline
Crude oil	3.7		0.4		1.5		—		5.6
NGLs	—		17.7		0.3		(17.7)		0.3
Transportation
NGLs	—		—		12.4		—		12.4
Rail Loading
Crude oil	—		—		0.6		—		0.6
Product Sales
Natural gas	95.1		113.6		211.9		(182.9)		237.7
Crude oil	377.2		1.1		954.4		(57.7)		1,275.0
NGLs	126.5		296.9		907.8		(91.3)		1,239.9
Water	2.9		—		—		—		2.9
Other	1.1		—		1.0		(0.4)		1.7
Total Topic 606 revenues	946.5		494.1		2,096.4		(350.2)		3,186.8
Non-Topic 606 revenues	1.6		(1.6)		236.9		—		236.9
Total revenues	$	948.1	$	492.5	$	2,333.3	$	(350.2)	$	3,423.7

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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	4.2		0.5		1.5		(0.1)		6.1
NGLs	—		5.2		0.2		(5.2)		0.2
Transportation
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

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. For a further description of our related party agreements, see our 2022 Annual Report on Form 10-K. During the nine months ended September 30, 2023, we paid approximately $1.0 million of capital expenditures to Applied Consultants, Inc., an affiliate of First Reserve.

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The following table shows transactions with our affiliates which are reflected in our consolidated statements of operations (in millions).

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Revenues at CEQP and CMLP(1)	$	—	$	140.8	$	—	$	372.7
Costs of product/services sold at CEQP and CMLP(2)	$	—	$	51.3	$	0.5	$	232.9
Operations and maintenance expenses at CEQP and CMLP(3)	$	1.0	$	2.6	$	4.6	$	12.4
General and administrative expenses charged by CEQP to CMLP, net(4)	$	5.4	$	8.5	$	22.4	$	23.5
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; (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 provided to a subsidiary of Chord; (iii) $0.3 million and $3.9 million during the three and nine months ended September 30, 2022 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) $0.3 million during the nine months ended September 30, 2023 and $0.3 million and $1.7 million during the three and nine months ended September 30, 2022 primarily related to purchases of natural gas from a subsidiary of Tres Holdings; (ii) $0.2 million during the nine months ended September 30, 2023 and $0.3 million during both the three and nine months ended September 30, 2022 related to gathering services under agreements with Crestwood Permian Basin; (iii) $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; and (iv) $9.2 million and $116.8 million during the three and nine months ended September 30, 2022 related to purchases of natural gas and NGLs from a subsidiary of Crestwood Permian.

(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 nine months ended September 30, 2023, we charged $1.5 million to Tres Holdings and during the three and nine months ended September 30, 2023, we charged $1.0 million and $3.1 million to Crestwood Permian Basin. 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.

(4)Includes $6.5 million and $25.7 million of unit-based compensation allocated from CEQP to CMLP during the three and nine months ended September 30, 2023 and $9.6 million and $26.8 million during the three and nine months ended September 30, 2022. 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, 2023 and $1.1 million and $3.3 million during the three and nine months ended September 30, 2022.

(5)Represents general and administrative expenses related to a transition services agreement with Chord.

The following table shows accounts receivable and accounts payable from our affiliates (in millions):

	September 30, 2023		December 31, 2022
Accounts receivable at CEQP and CMLP	$	0.4	$	1.6
Accounts payable at CEQP and CMLP	$	0.1	$	3.0

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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 unaudited consolidated financial statements and accompanying footnotes included in this Quarterly Report on Form 10-Q and Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations included in our 2022 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 facility 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 and global 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 and transportation infrastructure for hydrocarbons;

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

•changes in global economic conditions, including capital and credit market conditions, inflation and interest rates;

•costs or difficulties related to the integration of acquisitions;

•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);

•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 above, see Part I, Item 1A. Risk Factors of our 2022 Annual Report on Form 10-K.

Recent Developments

On November 3, 2023, Crestwood Equity is expected to merge with and into a direct wholly-owned subsidiary of Energy Transfer LP (Energy Transfer) in an all-equity transaction valued at approximately $7.1 billion (the Energy Transfer Merger). On August 16, 2023, Crestwood Equity entered into a merger agreement with Energy Transfer pursuant to which each Crestwood Equity common unit representing limited partner interests in Crestwood Equity issued and outstanding immediately prior to the Energy Transfer Merger will be converted into the right to receive 2.07 common units representing limited partner

36

interests in Energy Transfer. Each preferred unit representing limited partner interests in Crestwood Equity issued and outstanding immediately prior to the Energy Transfer Merger will, at the election of the holder of such preferred unit, be (i) converted into a preferred unit of Energy Transfer that has substantially similar terms, including with respect to economics and structural protections, as the preferred units of Crestwood Equity, (ii) redeemed in exchange for cash, at a price of 108% of the preferred unit price plus accrued and unpaid distributions to the date of such redemption, or (iii) converted into common units, at the then-applicable conversion ratio (one common unit for 10 preferred), subject to the payment of any accrued but unpaid distributions prior to Energy Transfer Merger. In connection with the Energy Transfer Merger and at the direction of Energy Transfer, Crestwood Equity conducted a consent solicitation pursuant to which Crestwood Equity solicited consent from the preferred unitholders to approve an amendment to its Sixth Amended and Restated Agreement of Limited Partnership. Pursuant to the proposed amendment, among other things, (i) the preferred unitholders electing a cash redemption in the Energy Transfer Merger would receive such cash redemption price as increased from 101% to 108% of the preferred unit price; and (ii) the preferred unitholders electing to receive preferred units of Energy Transfer would receive such preferred units of Energy Transfer with terms similar to Energy Transfer’s other outstanding series of preferred units. Crestwood Equity received the consents from the preferred unitholders necessary to approve the proposed amendment and therefore, the proposed amendment will be adopted at the closing of the Energy Transfer Merger.

CEQP is a publicly-traded Delaware limited partnership, and its common units are listed on the New York Stock Exchange (NYSE) under the ticker symbol “CEQP” and its preferred units are listed on the NYSE under the ticker symbol “CEQP-P.” In connection with the consummation of the Energy Transfer Merger, we requested that the NYSE delist our common and preferred units and, as a result, trading of our common and preferred units will be suspended on November 3, 2023. We also requested that the NYSE file a Form 25 with the SEC notifying the SEC of the delisting of our common and preferred units and the withdrawal of registration of our common and preferred units under Section 12(b) of the Exchange Act. Following the effectiveness of the Form 25, we intend to file with the SEC a Form 15 regarding the termination of registration of our common and preferred units under the Exchange Act and the suspension of reporting obligations with respect to our common and preferred units.

For more information regarding the merger and the merger agreement, see our Current Report on Form 8-K filed with the SEC on August 16, 2023 and our definitive merger proxy statement on Schedule 14A filed with the SEC on September 29, 2023.

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 (loss) before debt-related costs (interest and debt expense, net), income taxes 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, gains or losses on long-lived assets, 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 are 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 U.S. GAAP, as they do not include deductions for expenses 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 U.S. GAAP. EBITDA and Adjusted EBITDA calculations may vary among entities, so our computation may not be comparable to measures used by other companies. See our reconciliation of net income to EBITDA and Adjusted EBITDA in “Results of Operations” below.

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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,
	2023		2022		2023		2022		2023		2022		2023		2022
Revenues	$	1,139.4	$	1,566.0	$	3,423.7	$	4,597.8	$	1,139.4	$	1,566.0	$	3,423.7	$	4,597.8
Costs of product/services sold	901.6		1,286.8		2,683.6		3,864.4		901.6		1,286.8		2,683.6		3,864.4
Operations and maintenance expense	56.9		55.0		166.7		144.0		56.9		55.0		166.7		144.0
General and administrative expense	30.2		33.9		86.8		103.8		20.8		32.3		74.6		99.0
Depreciation, amortization and accretion	80.2		86.9		242.7		242.3		80.1		86.8		242.5		248.0
Loss on long-lived assets, net	2.6		175.9		4.8		186.9		2.6		247.6		4.8		311.9
Gain on acquisition	—		(75.3)		—		(75.3)		—		(75.3)		—		(75.3)
Operating income (loss)	67.9		2.8		239.1		131.7		77.4		(67.2)		251.5		5.8
Earnings from unconsolidated affiliates, net	1.1		3.2		135.2		12.2		1.1		3.2		135.2		12.2
Interest and debt expense, net	(56.9)		(47.6)		(167.9)		(123.8)		(56.9)		(47.6)		(167.9)		(123.8)
Other income, net	0.2		—		0.3		0.2		—		—		—		—
Provision for income taxes	(0.2)		(1.4)		(1.1)		(1.7)		(0.2)		(1.4)		(1.0)		(1.6)
Net income (loss)	12.1		(43.0)		205.6		18.6		21.4		(113.0)		217.8		(107.4)
Add:
Interest and debt expense, net	56.9		47.6		167.9		123.8		56.9		47.6		167.9		123.8
Provision for income taxes	0.2		1.4		1.1		1.7		0.2		1.4		1.0		1.6
Depreciation, amortization and accretion	80.2		86.9		242.7		242.3		80.1		86.8		242.5		248.0
EBITDA	$	149.4	$	92.9	$	617.3	$	386.4	$	158.6	$	22.8	$	629.2	$	266.0
Unit-based compensation	6.5		9.6		25.7		26.8		6.5		9.6		25.7		26.8
Loss on long-lived assets, net	2.6		175.9		4.8		186.9		2.6		247.6		4.8		311.9
Gain on acquisition	—		(75.3)		—		(75.3)		—		(75.3)		—		(75.3)
Earnings from unconsolidated affiliates, net	(1.1)		(3.2)		(135.2)		(12.2)		(1.1)		(3.2)		(135.2)		(12.2)
Adjusted EBITDA from unconsolidated affiliates, net	2.4		5.7		8.6		24.2		2.4		5.7		8.6		24.2
Change in fair value of commodity inventory-related derivative contracts	27.3		(5.4)		26.8		(4.6)		27.3		(5.4)		26.8		(4.6)
Significant transaction and environmental related costs and other items	9.6		9.1		17.2		29.6		1.4		9.1		9.0		29.6
Adjusted EBITDA	$	196.7	$	209.3	$	565.2	$	561.8	$	197.7	$	210.9	$	568.9	$	566.4

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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,
	2023		2022		2023		2022		2023		2022		2023		2022
Net cash provided by operating activities	$	111.4	$	25.3	$	378.5	$	277.3	$	120.9	$	26.9	$	391.5	$	282.1
Net changes in operating assets and liabilities	(9.1)		129.9		(30.5)		123.9		(9.2)		129.8		(31.2)		123.9
Amortization of debt-related deferred costs and fair value adjustment	(0.9)		(0.5)		(2.5)		(1.7)		(0.9)		(0.5)		(2.5)		(1.7)
Interest and debt expense, net	56.9		47.6		167.9		123.8		56.9		47.6		167.9		123.8
Unit-based compensation	(6.5)		(9.6)		(25.7)		(26.8)		(6.5)		(9.6)		(25.7)		(26.8)
Loss on long-lived assets, net	(2.6)		(175.9)		(4.8)		(186.9)		(2.6)		(247.6)		(4.8)		(311.9)
Gain on acquisition	—		75.3		—		75.3		—		75.3		—		75.3
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	0.1		0.7		133.3		0.9		0.1		0.7		133.3		0.9
Deferred income taxes	0.1		(1.2)		0.1		(1.1)		(0.1)		(1.1)		(0.2)		(1.2)
Provision for income taxes	0.2		1.4		1.1		1.7		0.2		1.4		1.0		1.6
Other non-cash expense	(0.2)		(0.1)		(0.1)		—		(0.2)		(0.1)		(0.1)		—
EBITDA	$	149.4	$	92.9	$	617.3	$	386.4	$	158.6	$	22.8	$	629.2	$	266.0
Unit-based compensation	6.5		9.6		25.7		26.8		6.5		9.6		25.7		26.8
Loss on long-lived assets, net	2.6		175.9		4.8		186.9		2.6		247.6		4.8		311.9
Gain on acquisition	—		(75.3)		—		(75.3)		—		(75.3)		—		(75.3)
Earnings from unconsolidated affiliates, net	(1.1)		(3.2)		(135.2)		(12.2)		(1.1)		(3.2)		(135.2)		(12.2)
Adjusted EBITDA from unconsolidated affiliates, net	2.4		5.7		8.6		24.2		2.4		5.7		8.6		24.2
Change in fair value of commodity inventory-related derivative contracts	27.3		(5.4)		26.8		(4.6)		27.3		(5.4)		26.8		(4.6)
Significant transaction and environmental related costs and other items	9.6		9.1		17.2		29.6		1.4		9.1		9.0		29.6
Adjusted EBITDA	$	196.7	$	209.3	$	565.2	$	561.8	$	197.7	$	210.9	$	568.9	$	566.4

Segment Results

The following tables and discussion are a summary of EBITDA by segment for the three and nine months ended September 30, 2023 compared to the same periods in 2022 (in millions):

	Three Months Ended						Three Months Ended
	September 30, 2023						September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Gathering and Processing North		Gathering and Processing South		Storage and Logistics
Revenues	$	262.8	$	123.0	$	753.6	$	272.6	$	177.4	$	1,116.0
Intersegment revenues	70.9		52.5		(123.4)		142.2		137.8		(280.0)
Costs of product/services sold	158.4		121.1		622.1		230.2		249.6		807.0
Operations and maintenance expenses	29.9		14.9		12.1		27.4		14.3		13.3
Loss on long-lived assets, net	—		—		(2.6)		—		(247.6)		—
Gain on acquisition	—		—		—		—		75.3		—
Earnings from unconsolidated affiliates, net	—		1.1		—		—		2.0		1.2
Crestwood Midstream EBITDA	$	145.4	$	40.6	$	(6.6)	$	157.2	$	(119.0)	$	16.9
Gain on long-lived assets	—		—		—		—		71.7		—
Crestwood Equity EBITDA	$	145.4	$	40.6	$	(6.6)	$	157.2	$	(47.3)	$	16.9

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	Nine Months Ended						Nine Months Ended
	September 30, 2023						September 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Gathering and Processing North		Gathering and Processing South		Storage and Logistics
Revenues	$	717.1	$	373.3	$	2,333.3	$	787.2	$	243.4	$	3,567.2
Intersegment revenues	231.0		119.2		(350.2)		421.2		137.8		(559.0)
Costs of product/services sold	447.7		329.8		1,906.1		686.6		249.6		2,928.2
Operations and maintenance expenses	85.6		45.2		35.9		78.6		28.6		36.8
Gain (loss) on long-lived assets, net	0.1		(2.7)		(2.6)		—		(307.8)		(4.1)
Gain on acquisition	—		—		—		—		75.3		—
Earnings from unconsolidated affiliates, net	—		2.0		133.2		—		9.4		2.8
Crestwood Midstream EBITDA	$	414.9	$	116.8	$	171.7	$	443.2	$	(120.1)	$	41.9
Gain on long-lived assets(1)	—		—		—		—		125.0		—
Crestwood Equity EBITDA	$	414.9	$	116.8	$	171.7	$	443.2	$	4.9	$	41.9

(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 legacy assets in the Barnett Shale. For a further discussion of this transaction, see Item 1. Financial Statements, Note 3.

Gathering and Processing North

EBITDA for our gathering and processing north segment decreased by approximately $11.8 million and $28.3 million during the three and nine months ended September 30, 2023 compared to the same periods in 2022. Our gathering and processing north segment’s revenues decreased by approximately $81.1 million and $260.3 million during the three and nine months ended September 30, 2023 compared to the same periods in 2022, while our costs of product/services sold decreased by approximately $71.8 million and $238.9 million during those same periods. These decreases were primarily driven by declines in commodity prices experienced during 2023 compared to 2022.

During the three and nine months ended September 30, 2023, our Arrow operations experienced lower average commodity prices on natural gas, NGLs and crude oil it purchases and sells pursuant to its agreements, which decreased by more than 50%, 30% and 20%, respectively, compared to the same periods in 2022, and largely contributed to the decrease in our gathering and processing north segment’s revenues and costs of product/services sold period over period. We manage our company-wide oil, natural gas and NGL commodity exposures through price risk management activities conducted by our storage and logistics segment, which is further described under Storage and Logistics below. In addition, Arrow’s natural gas gathering and processing volumes both decreased by approximately 10% during the three and nine months ended September 30, 2023 compared to the same periods in 2022. These decreases were primarily due to downtime experienced by our producer customers related to maintenance and completion activity associated with new well connections and unusual weather conditions experienced at the end of 2022 and into early 2023.

During the three and nine months ended September 30, 2023, our Rough Rider operations also experienced a decrease in its revenues and costs of product/services sold compared to the same periods in 2022, which was partially offset by an increase in its natural gas gathering and processing volumes and its crude oil and water gathering volumes. During the nine months ended September 30, 2023, our Rough Rider operations experienced an increase in its natural gas gathering and processing volumes of approximately 10% and 6% respectively, compared to the same period in 2022 due to the full contribution from these operations during the nine months ended September 30, 2023. Our Rough Rider operations’ crude oil and water gathering volumes increased by approximately 71% and 28%, respectively, compared to the same period in 2022. These increases were due primarily to placing in service a three-product gathering system, increased activity from our producer customers related to new well connections and the full contribution from these operations during the nine months ended September 30, 2023.

Our gathering and processing north segment’s operations and maintenance expenses increased by approximately $2.5 million and $7.0 million during the three and nine months ended September 30, 2023 compared to the same periods in 2022, primarily due to our Rough Rider operations acquired in conjunction with the merger with Oasis Midstream in February 2022.

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Gathering and Processing South

EBITDA for CMLP’s gathering and processing south segment increased by approximately $159.6 million and $236.9 million during the three and nine months ended September 30, 2023 compared to the same periods in 2022. CMLP’s gathering and processing south segment’s EBITDA during the nine months ended September 30, 2022 was impacted by the CPJV Acquisition as well as the divestitures of our operations in the Barnett and Marcellus Shales described below. For a further discussion of these transactions, see Item 1. Financial Statements, Note 3.

Our gathering and processing south segment’s revenues and costs of product/services sold decreased by approximately $139.7 million and $128.5 million, respectively, during the three months ended September 30, 2023 compared to the same period in 2022. These decreases were primarily driven by the divestiture of our Marcellus operations in late 2022 and by lower average commodity prices experienced by our gathering and processing south segment on its natural gas gathering agreements compared to the same period in 2022. During the three months ended September 30, 2023, our gathering and processing south segment’s operations and maintenance expenses were relatively flat compared to the same period in 2022.

Our gathering and processing south segment’s revenues, costs of product/services sold and operations and maintenance expenses increased by approximately $111.3 million, $80.2 million and $16.6 million, respectively, during the nine months ended September 30, 2023 compared to the same period in 2022. These increases were primarily driven by the impact of the Sendero Acquisition and the CPJV Acquisition in July 2022, which increased our gathering and processing south segment’s revenues, costs of product/services sold and operations and maintenance expenses by approximately $175.0 million, $77.2 million, and $31.5 million, respectively, during the nine months ended September 30, 2023 compared to the same period in 2022. In addition, during the nine months ended September 30, 2022, CMLP recognized a gain of approximately $75 million related to the CPJV Acquisition.

Partially offsetting the increases described above were the divestitures of our Barnett and Marcellus legacy, non-core operations during 2022, which decreased our gathering and processing south segment’s revenues and operations and maintenance expenses by approximately $68.6 million and $16.4 million, respectively, during the nine months ended September 30, 2023 compared to the same period in 2022. In addition, during the nine months ended September 30, 2022, CMLP recorded a loss on long-lived assets related to the Barnett and Marcellus divestitures of approximately $53 million and $248 million, respectively.

Also impacting CMLP’s 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 sale of parts inventory related to our legacy Granite Wash operations.

CMLP’s gathering and processing south segment’s EBITDA was also impacted by a decrease in earnings from unconsolidated affiliates of approximately $0.9 million and $7.4 million during the three and nine months ended September 30, 2023 compared to the same periods in 2022, primarily due to the consolidation of our Crestwood Permian equity investment as a result of acquiring the remaining 50% equity interest in Crestwood Permian in July 2022.

EBITDA for CEQP’s gathering and processing south segment increased by approximately $87.9 million and $111.9 million during the three and nine months ended September 30, 2023 compared to the same periods in 2022. The change in CEQP’s gathering and processing south segment’s EBITDA period over period was due to 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 our Barnett operations due to historical impairments previously recorded by CEQP on Barnett’s long-lived assets. During the three months ended September 30, 2022, CEQP recorded a gain on the Barnett divestiture of approximately $72 million.

Storage and Logistics

EBITDA for our storage and logistics segment decreased by approximately $23.5 million during the three months ended September 30, 2023 compared to the same period in 2022, while our storage and logistics segment’s EBITDA increased by approximately $129.8 million during the nine months ended September 30, 2023 compared to the same period in 2022. Our storage and logistics segment’s EBITDA for the nine months ended September 30, 2023 was impacted by a $132 million increase to the equity earnings from our Tres Holdings equity method investment as a result of recording a gain on the sale of the equity method investment as further discussed below.

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Our storage and logistics segment’s revenues decreased by $205.8 million and $1,025.1 million during the three and nine months ended September 30, 2023 compared to the same periods in 2022, and our costs of product/services sold decreased by $184.9 million and $1,022.1 million during those same periods.

Our NGL marketing and logistics operations experienced a decrease in revenues of approximately $160.4 million and $681.3 million during the three and nine months ended September 30, 2023 compared to the same periods in 2022, and a decrease in costs of product/services sold of approximately $137.1 million and $683.1 million during those same periods. These decreases were primarily driven by lower NGL prices during 2023 compared to 2022. Included in our costs of product/services sold was a loss of $18.0 million and a gain of $13.5 million during the three and nine months ended September 30, 2023, and a gain of $45.0 million and a loss of $6.3 million during the three and nine months ended September 30, 2022 related to our price risk management activities, which were also driven by the volatility in commodity prices described above.

Our crude oil and natural gas marketing operations experienced a decrease in its revenues of approximately $45.4 million and $343.7 million during the three and nine months ended September 30, 2023, compared to the same periods in 2022, and a decrease in product costs of approximately $47.8 million and $339.1 million during those same periods. These decreases were primarily driven by lower crude oil purchases and sales as a result of decreases in commodity prices during 2023 compared to 2022.

During the three months ended September 30, 2023, our storage and logistics segment’s EBITDA was impacted by a loss on long-lived assets of approximately $2.6 million primarily related to the sale of our transportation assets in August 2023. Also impacting our storage and logistics segment’s EBITDA during the nine months ended September 30, 2022 was a loss on long-lived assets of approximately $4.1 million primarily due to the buyout of leases related to our exiting the crude oil railcar leasing business.

Our storage and logistics segment’s EBITDA was also impacted by a net increase in earnings from unconsolidated affiliates of approximately $130.4 million during the nine months ended September 30, 2023 compared to the same period in 2022. On April 3, 2023, we and Brookfield sold our respective interests in Tres Holdings to a subsidiary of Enbridge, Inc. We recorded a gain on the sale of approximately $132 million, which we reflected as an increase to the equity earnings from our Tres Holding equity method investment. For a further discussion of the sale of our Tres Holding equity investment, see Item 1. Financial Statements, Note 5.

Other EBITDA Results

General and Administrative Expenses. During the three and nine months ended September 30, 2023, our general and administrative expenses decreased compared to the same periods in 2022, primarily due to transactions costs incurred in connection with our strategic transactions executed during 2022.

Items not affecting EBITDA include the following:

Depreciation, Amortization and Accretion Expense. During the three months ended September 30, 2023, CMLP’s and CEQP’s depreciation, amortization and accretion expense decreased by approximately $6.7 million compared to the same period in 2022, primarily due to the divestiture of our Marcellus operations in late 2022, partially offset by our acquisitions of Sendero and Crestwood Permian in July 2022. During the nine months ended September 30, 2023, CMLP’s depreciation, amortization and accretion expense decreased by approximately $5.5 million, primarily due to the divestitures of our legacy Barnett and Marcellus operations in 2022, partially offset by our acquisitions during 2022. During the nine months ended September 30, 2023, CEQP’s depreciation, amortization and accretion expense was relatively flat. For a further discussion of our acquisitions and divestitures during 2022, see Item 1. Financial Statements, Note 3.

Interest and Debt Expense, Net. During the three and nine months ended September 30, 2023, our interest and debt expense, net increased by approximately $9.3 million and $44.1 million compared to the same periods in 2022, primarily due to the 2031 Senior Notes issued in January 2023 and higher interest rates on borrowings under the CMLP Credit Facility during 2023 compared to 2022.

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

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Credit facilities	$	10.2	$	12.8	$	30.6	$	21.5
Senior notes	46.1		35.2		136.4		102.4
Other, net	0.8		0.5		2.9		1.8
Gross interest and debt expense	57.1		48.5		169.9		125.7
Less: capitalized interest	0.2		0.9		2.0		1.9
Interest and debt expense, net	$	56.9	$	47.6	$	167.9	$	123.8

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 the CMLP credit facility, 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 pay 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. On October 12, 2023, the board of directors of our general partner declared a quarterly cash distribution of $0.655 per unit to our common unitholders with respect to the quarter ended September 30, 2023. In addition, the board of directors declared a special cash distribution of $0.003 per limited partner unit in conjunction with the Energy Transfer Merger. We also pay quarterly cash distributions to our preferred unitholders, and on October 12, 2023, the board of directors of our general partner declared a cash distribution of approximately $15 million with respect to the quarter ended September 30, 2023. In addition, the board of directors declared a special cash distribution of $0.0003 per preferred unit in conjunction with the Energy Transfer Merger. The cash distributions related to our common and preferred unitholders were paid on October 31, 2023 to common and preferred unitholders of record on October 23, 2023.

We pay quarterly cash distributions of approximately $10 million to Crestwood Niobrara’s non-controlling partner. In conjunction with the merger agreement we entered into with Energy Transfer in August 2023, the Crestwood Niobrara preferred units became currently redeemable and as a result, we reflected the Crestwood Niobrara preferred units at their Change of Control Redemption Price (as defined in the agreement ), which is equal to 105% of the liquidation value. During the three months ended September 30, 2023, we recorded an increase of approximately $22 million to net income attributable to non-controlling partner to reflect the Crestwood Niobrara preferred units at their maximum liquidation value.

As of September 30, 2023, we had $872.0 million of available capacity under the Crestwood Midstream credit facility, considering the most restrictive debt covenants in the credit agreement. As of September 30, 2023, we were in compliance with all of our debt covenants applicable to our credit facility and senior notes. See Item 1. Financial Statements, Note 8 for a description of the covenants related to our credit facility.

In January 2023, Crestwood Midstream issued $600 million of 7.375% unsecured senior notes due 2031 (the 2031 Senior Notes). We used the net proceeds from the issuance of the 2031 Senior Notes to repay borrowings under the Crestwood Midstream credit facility and to repay all outstanding borrowings under the Crestwood Permian credit facility, which was terminated in January 2023. In April 2023, we sold our 50% equity interest in Tres Holdings for approximately $178 million, including working capital adjustments, and we used the proceeds from the sale to repay amounts outstanding under the Crestwood Midstream credit facility.

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Cash Flows

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

	Nine Months Ended
	September 30,
	2023		2022
Net cash provided by operating activities	$	378.5	$	277.3
Net cash provided by (used in) investing activities	$	21.4	$	(517.2)
Net cash provided by (used in) financing activities	$	(383.6)	$	233.0

Operating Activities

Our cash flows from operating activities increased by approximately $101.2 million during the nine months ended September 30, 2023 compared to the same period in 2022. The net increase was primarily driven by our gathering and processing operations acquired in the Delaware Basin during 2022, partially offset by a reduction in operating cash flows from our Barnett and Marcellus operations which were divested during 2022. In addition, our general and administrative expenses decreased during the nine months ended September 30, 2023 compared to the same period in 2022, primarily due to transaction costs incurred in connection with our strategic transactions executed during 2022.

Investing Activities

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.

Our growth and reimbursable capital expenditures during the year increase the services we can provide to our customers and the operating efficiencies of our systems. Additional commitments or expenditures are made at the discretion of management, and any discontinuation of the construction of these 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, 2023 (in millions):

Growth capital(1)	$	130.9
Maintenance capital	21.9
Other(2)	11.2
Purchases of property, plant and equipment	$	164.0

(1)Includes payments of approximately $21 million related to 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.

Acquisitions and Divestitures.

•Oasis Merger. In February 2022, we acquired Oasis Midstream, which included cash consideration of $160 million, net of cash acquired of approximately $14.9 million.

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

•CPJV Acquisition. In July 2022, we acquired First Reserve’s 50% equity interest in Crestwood Permian, which included cash consideration of approximately $5.9 million, net of cash acquired of approximately $149.4 million.

•Tres Holdings Divestiture. In April 2023, we sold our 50% equity interest in Tres Holdings for approximately $178.4 million.

•Transportation Assets Sale. In August 2023, we sold our transportation assets for approximately $8.0 million.

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•Crude Oil Railcars Sale. In April 2022, we sold our crude oil railcars for approximately $24.7 million primarily as a result of the exit of our crude railcar operations.

•Barnett Divestiture. In July 2022, we sold our assets in the Barnett Shale for approximately $290 million, including working capital adjustments.

Investments in Unconsolidated Affiliates. Pursuant to our joint venture agreements with our respective equity investments, we periodically make contributions to our equity investments to fund their expansion projects and for other operating purposes. During the nine months ended September 30, 2023 and 2022, we contributed approximately $7.2 million and $90.2 million to our equity investments.

Financing Activities

The following equity and debt transactions impacted our financing activities during the nine months ended September 30, 2023 compared to the same period in 2022:

•During the nine months ended September 30, 2023, distributions to our partners increased by approximately $10.0 million compared to the same period in 2022, primarily due to an increase in common units outstanding as a result of the units issued in conjunction with our strategic transactions during 2022 as well as an increase in our distribution per limited partner unit from $0.625 per unit to $0.655 per unit beginning in the second quarter of 2022;

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

•During the nine months ended September 30, 2022, payments under our finance leases increased primarily due to an option we exercised to purchase crude oil railcars under certain of our finance leases;

•During the nine months ended September 30, 2023, our taxes paid for unit-based compensation vesting increased by approximately $4.7 million compared to the same period in 2022, primarily due to higher vesting of unit-based compensation awards;

•During the nine months ended September 30, 2023, we received approximately $592.5 million from the issuance of the 2031 Senior Notes;

•During the nine months ended September 30, 2022, we borrowed amounts under the Crestwood Midstream 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 merger with Oasis Midstream; and (iv) to repay approximately $218.4 million outstanding under the credit facility acquired in conjunction with the merger with Oasis Midstream; and

• During the nine months ended September 30, 2023, our other debt-related transactions resulted in net repayments under our credit facilities of approximately $670.8 million compared to net repayments of approximately $243.7 million during the same period in 2022.

Guarantor Summarized Financial Information

Crestwood Midstream and Crestwood Midstream Finance Corp. are issuers of our 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 and its credit facility are jointly and severally guaranteed by substantially all of its subsidiaries (collectively, the Guarantor Subsidiaries), except for Crestwood Infrastructure Holdings LLC, Crestwood Niobrara LLC, and Powder River Basin Industrial Complex 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. In January 2023, Crestwood Permian and certain of its subsidiaries were designated as Guarantor Subsidiaries of Crestwood Midstream’s senior notes and its credit facility. For additional information regarding the Crestwood Midstream credit facility and senior notes and related guarantees, see our 2022 Annual Report on Form 10-K.

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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.

Summarized Combined Balance Sheet Information (in millions)

	September 30, 2023		December 31, 2022
Current assets	$	580.7	$	588.4
Current assets - affiliates	$	1.3	$	1.3
Property, plant and equipment, net	$	3,779.2	$	3,295.8
Non-current assets	$	981.7	$	1,012.9
Current liabilities	$	445.8	$	466.1
Current liabilities - affiliates	$	2.8	$	41.5
Long-term debt, less current portion	$	3,302.5	$	3,171.5
Non-current liabilities	$	197.0	$	147.6

Summarized Combined Statement of Operations Information (in millions)

	Nine Months Ended September 30, 2023
Revenues	$	3,370.5
Revenues - affiliates	$	0.8
Cost of products/services sold	$	2,670.5
Cost of products/services sold - affiliates	$	13.8
Operations and maintenance expenses(1)	$	152.0
General and administrative expenses(2)	$	74.6
Operating income	$	259.4
Net income	$	90.3

(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, 2023, we charged $12.3 million to our affiliates under these agreements.

(2)    Includes $22.4 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, commodity price, market and credit risks are discussed in our 2022 Annual Report on Form 10-K. There have been no material changes in those exposures from December 31, 2022 to September 30, 2023.

Item 4.Controls and Procedures

Disclosure Controls and Procedures

As of September 30, 2023, 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,

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including the Chief Executive Officer and Chief Financial Officer of their General Partners, does 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 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, 2023.

Changes in Internal Control over Financial Reporting

There have been no changes in Crestwood Equity’s or Crestwood Midstream’s internal control over financial reporting during the three and nine months ended September 30, 2023 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 2022 Annual Report on Form 10-K.

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

None.

Item 3.Defaults Upon Senior Securities

None.

Item 4.Mine Safety Disclosures

Not applicable.

Item 5.Other Information

During the three months ended September 30, 2023, none of our directors of officers (as defined in Rule 16a-1(f) of the Securities Exchange Act of 1934) adopted, terminated or modified a Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement (as such terms are defined in Item 408 of Regulation S-K).

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)

48

2.4	Agreement and Plan of Merger, dated as of August 16, 2023, by and among Energy Transfer LP, Pachyderm Merger Sub LLC, Crestwood Equity Partners LP and, solely for the purposes set forth therein, LE GP, LLC. (incorporated by reference to Exhibit 2.1 to Crestwood Equity Partners LP’s Form 8-K, filed on August 16, 2023)
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)
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)

49

10.1	Employment Agreement between Jeffrey C. Cathey and Crestwood Operations LLC, dated April 14, 2021 (incorporated by reference to Exhibit 10.1 to Crestwood Equity Partners LP’s Form 8-K filed on June 29, 2023)
10.2	Fourth Amended and Restated Limited Liability Company Agreement of Crestwood Niobrara LLC effective as of July 25, 2023 (incorporated by reference to Exhibit 10.1 to Crestwood Equity Partners LP’s Form 8-K filed on July 27, 2023)
10.3	Form of Director and Officer Indemnification Agreement (incorporated by reference to Exhibit 10.1 to Crestwood Equity Partners LP’s Form 8-K filed on August 16, 2023)
*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.

50

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 2, 2023	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 2, 2023	By:	/s/ JOHN BLACK
			John Black
			Executive Vice President and Chief Financial Officer
			(Duly Authorized Officer and Principal Financial Officer)

51

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 2, 2023

/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 2, 2023

/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 2, 2023

/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 2, 2023

/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, 2023, 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 2, 2023	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, 2023, 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 2, 2023	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, 2023, 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 2, 2023	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, 2023, 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 2, 2023	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, 2023	Oct. 27, 2023
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	2023
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		105,098,724
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, 2023
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	2023
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, 2023
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, 2023	Dec. 31, 2022
Assets
Cash	$ 23.8	$ 7.5
Accounts receivable, less allowance for doubtful accounts of $0.5 at both September 30, 2023 and December 31, 2022	350.1	432.2
Inventory	179.9	122.6
Assets from price risk management activities	38.0	72.8
Prepaid expenses and other current assets	8.5	18.7
Total current assets	600.3	653.8
Property, plant and equipment	5,467.5	5,353.2
Less: accumulated depreciation	999.6	822.8
Property, plant and equipment, net	4,467.9	4,530.4
Intangible assets	1,234.6	1,306.3
Less: accumulated amortization	277.9	300.7
Intangible assets, net	956.7	1,005.6
Goodwill	223.0	223.0
Operating lease right-of-use assets, net	23.3	24.4
Investments in unconsolidated affiliates	77.1	119.5
Other non-current assets	11.5	10.3
Total assets	6,359.8	6,567.0
Current liabilities:
Accounts payable	256.9	305.5
Accrued expenses and other liabilities	183.6	180.8
Liabilities from price risk management activities	17.6	23.9
Total current liabilities	458.1	510.2
Long-term debt, less current portion	3,302.5	3,378.3
Other long-term liabilities	323.4	333.4
Deferred income taxes	3.4	3.5
Total liabilities	4,087.4	4,225.4
Commitments and contingencies (Note 9)
Interest of non-controlling partner in subsidiary	456.0	434.4
Partners’ capital:
Crestwood Equity Partners LP partners’ capital (105,099,889 and 104,646,374 common units issued and outstanding at September 30, 2023 and December 31, 2022)	1,204.4	1,295.2
Preferred units (71,257,445 units issued and outstanding at both September 30, 2023 and December 31, 2022)	612.0	612.0
Total partners’ capital	1,816.4	1,907.2
Total liabilities and capital	6,359.8	6,567.0
Crestwood Midstream Partners LP
Assets
Cash	23.4	7.1
Accounts receivable, less allowance for doubtful accounts of $0.5 at both September 30, 2023 and December 31, 2022	350.0	432.2
Inventory	179.9	122.6
Assets from price risk management activities	38.0	72.8
Prepaid expenses and other current assets	8.5	18.7
Total current assets	599.8	653.4
Property, plant and equipment	5,464.3	5,350.0
Less: accumulated depreciation	999.3	822.6
Property, plant and equipment, net	4,465.0	4,527.4
Intangible assets	1,234.6	1,306.3
Less: accumulated amortization	277.9	300.7
Intangible assets, net	956.7	1,005.6
Goodwill	223.0	223.0
Operating lease right-of-use assets, net	23.3	24.4
Investments in unconsolidated affiliates	77.1	119.5
Other non-current assets	9.3	8.1
Total assets	6,354.2	6,561.4
Current liabilities:
Accounts payable	256.9	305.4
Accrued expenses and other liabilities	182.7	179.5
Liabilities from price risk management activities	17.6	23.9
Total current liabilities	457.2	508.8
Long-term debt, less current portion	3,302.5	3,378.3
Other long-term liabilities	321.3	330.3
Deferred income taxes	2.5	2.3
Total liabilities	4,083.5	4,219.7
Commitments and contingencies (Note 9)
Interest of non-controlling partner in subsidiary	456.0	434.4
Partners’ capital:
Partners' capital	1,814.7	1,907.3
Total liabilities and capital	$ 6,354.2	$ 6,561.4

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Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Allowance for doubtful accounts	$ 0.5
Limited Partners' Capital Account, Units Issued	105,099,889	104,646,374
Limited Partners' Capital Account, Units Outstanding	105,099,889	104,646,374
Preferred Units, Issued	71,257,445	71,257,445
Preferred Units, Outstanding	71,257,445	71,257,445
Crestwood Midstream Partners LP
Allowance for doubtful accounts	$ 0.5	$ 0.5

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Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Revenues:
Total revenues	$ 1,139.4	$ 1,566.0	$ 3,423.7	$ 4,597.8
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	901.6	1,286.8	2,683.6	3,864.4
Operating expenses and other:
Operations and maintenance	56.9	55.0	166.7	144.0
General and administrative	30.2	33.9	86.8	103.8
Depreciation, amortization and accretion	80.2	86.9	242.7	242.3
Loss on long-lived assets, net	2.6	175.9	4.8	186.9
Gain on acquisition	0.0	(75.3)	0.0	(75.3)
Total expenses	169.9	276.4	501.0	601.7
Operating income (loss)	67.9	2.8	239.1	131.7
Earnings from unconsolidated affiliates, net	1.1	3.2	135.2	12.2
Interest and debt expense, net	(56.9)	(47.6)	(167.9)	(123.8)
Other income, net	0.2	0.0	0.3	0.2
Income (loss) before income taxes	12.3	(41.6)	206.7	20.3
Provision for income taxes	(0.2)	(1.4)	(1.1)	(1.7)
Net income (loss)	12.1	(43.0)	205.6	18.6
Net income attributable to non-controlling partner	32.1	10.3	52.6	30.8
Net income (loss) attributable to parent	(20.0)	(53.3)	153.0	(12.2)
Net income attributable to preferred unit holders	15.1	15.0	45.1	45.0
Net income (loss) attributable to partners	$ (35.1)	$ (68.3)	$ 107.9	$ (57.2)
Net income (loss) per limited partner unit: (Note 12)
Basic (in dollars per share)	$ (0.33)	$ (0.64)	$ 1.03	$ (0.59)
Diluted (in dollars per share)	$ (0.33)	$ (0.64)	$ 0.99	$ (0.59)
Weighted-average limited partners’ units outstanding:
Basic (units)	105.2	107.1	105.2	97.1
Dilutive units (units)	0.0	0.0	3.9	0.0
Diluted (units)	105.2	107.1	109.1	97.1
Crestwood Midstream Partners LP
Revenues:
Total revenues	$ 1,139.4	$ 1,566.0	$ 3,423.7	$ 4,597.8
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	901.6	1,286.8	2,683.6	3,864.4
Operating expenses and other:
Operations and maintenance	56.9	55.0	166.7	144.0
General and administrative	20.8	32.3	74.6	99.0
Depreciation, amortization and accretion	80.1	86.8	242.5	248.0
Loss on long-lived assets, net	2.6	247.6	4.8	311.9
Gain on acquisition	0.0	(75.3)	0.0	(75.3)
Total expenses	160.4	346.4	488.6	727.6
Operating income (loss)	77.4	(67.2)	251.5	5.8
Earnings from unconsolidated affiliates, net	1.1	3.2	135.2	12.2
Interest and debt expense, net	(56.9)	(47.6)	(167.9)	(123.8)
Income (loss) before income taxes	21.6	(111.6)	218.8	(105.8)
Provision for income taxes	(0.2)	(1.4)	(1.0)	(1.6)
Net income (loss)	21.4	(113.0)	217.8	(107.4)
Net income attributable to non-controlling partner	32.1	10.3	52.6	30.8
Net income (loss) attributable to parent	(10.7)	(123.3)	165.2	(138.2)
Crestwood Midstream Partners LP | Related Party
Operating expenses and other:
General and administrative	1.1	1.1	3.3	3.3
Product | Nonrelated Party
Revenues:
Total revenues	989.2	1,332.8	2,991.5	3,938.3
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	898.1	1,228.6	2,668.1	3,613.4
Product | Related Party
Revenues:
Total revenues	0.0	83.2	0.0	222.7
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	0.0	51.3	0.5	232.9
Product | Crestwood Midstream Partners LP | Nonrelated Party
Revenues:
Total revenues	989.2	1,332.8	2,991.5	3,938.3
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	898.1	1,228.6	2,668.1	3,613.4
Product | Crestwood Midstream Partners LP | Related Party
Revenues:
Total revenues	0.0	83.2	0.0	222.7
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	0.0	51.3	0.5	232.9
Service | Nonrelated Party
Revenues:
Total revenues	150.2	92.4	432.2	286.8
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	3.5	6.9	15.0	18.1
Service | Related Party
Revenues:
Total revenues	0.0	57.6	0.0	150.0
Service | Crestwood Midstream Partners LP | Nonrelated Party
Revenues:
Total revenues	150.2	92.4	432.2	286.8
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	3.5	6.9	15.0	18.1
Service | Crestwood Midstream Partners LP | Related Party
Revenues:
Total revenues	$ 0.0	$ 57.6	$ 0.0	$ 150.0

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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	Common Stock
Preferred units, beginning balance (in units) at Dec. 31, 2021							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
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
Unit-based compensation charges (in shares)								1,600,000
Unit-based compensation			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							71,300,000
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
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							71,300,000
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
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			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]
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)
Retirement of common units (Note 11) (in shares)								(4,600,000)
Unit-based compensation			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							71,300,000
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
Preferred units, beginning balance (in units) at Dec. 31, 2022	71,257,445						71,300,000
Partner units, beginning balance (in units) at Dec. 31, 2022								104,600,000
Beginning balance at Dec. 31, 2022		612.0	1,295.2	1,907.2	1,907.3	1,907.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(15.0)	(68.9)	(83.9)		(85.9)
Unit-based compensation charges (in shares)								1,100,000
Unit-based compensation			11.8	11.8		11.8
Taxes paid for unit-based compensation vesting (in shares)								(500,000)
Taxes paid for unit-based compensation vesting			(14.8)	(14.8)		(14.8)
Other (in shares)								100,000
Other			1.6	1.6
Net income (loss) attributable to parent		15.0	16.4	31.4		32.8
Preferred units, ending balance (in units) at Mar. 31, 2023							71,300,000
Partner units, ending balance (in units) at Mar. 31, 2023								105,300,000
Ending Balance at Mar. 31, 2023		612.0	1,241.3	1,853.3		1,851.2
Preferred units, beginning balance (in units) at Dec. 31, 2022	71,257,445						71,300,000
Partner units, beginning balance (in units) at Dec. 31, 2022								104,600,000
Beginning balance at Dec. 31, 2022		612.0	1,295.2	1,907.2	1,907.3	1,907.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss) attributable to parent	$ 153.0				165.2
Preferred units, ending balance (in units) at Sep. 30, 2023	71,257,445						71,300,000
Partner units, ending balance (in units) at Sep. 30, 2023								105,100,000
Ending Balance at Sep. 30, 2023		612.0	1,204.4	1,816.4	1,814.7	1,814.7
Preferred units, beginning balance (in units) at Mar. 31, 2023							71,300,000
Partner units, beginning balance (in units) at Mar. 31, 2023								105,300,000
Beginning balance at Mar. 31, 2023		612.0	1,241.3	1,853.3		1,851.2
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(15.0)	(68.9)	(83.9)		(85.4)
Unit-based compensation			9.2	9.2		9.2
Taxes paid for unit-based compensation vesting (in shares)								(100,000)
Taxes paid for unit-based compensation vesting			(0.8)	(0.8)		(0.8)
Other			(0.2)	(0.2)
Net income (loss) attributable to parent		15.0	126.6	141.6		143.1
Preferred units, ending balance (in units) at Jun. 30, 2023							71,300,000
Partner units, ending balance (in units) at Jun. 30, 2023								105,200,000
Ending Balance at Jun. 30, 2023		612.0	1,307.2	1,919.2		1,917.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(15.1)	(68.9)	(84.0)		(93.5)
Unit-based compensation			6.5	6.5		6.5
Taxes paid for unit-based compensation vesting (in shares)								(100,000)
Taxes paid for unit-based compensation vesting			(4.9)	(4.9)		(4.9)
Other			(0.4)	(0.4)
Net income (loss) attributable to parent	$ (20.0)	15.1	(35.1)	(20.0)	(10.7)	(10.7)
Preferred units, ending balance (in units) at Sep. 30, 2023	71,257,445						71,300,000
Partner units, ending balance (in units) at Sep. 30, 2023								105,100,000
Ending Balance at Sep. 30, 2023		$ 612.0	$ 1,204.4	$ 1,816.4	$ 1,814.7	$ 1,814.7

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Consolidated Statements of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Operating activities
Net income	$ 205.6	$ 18.6
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	242.7	242.3
Amortization of debt-related deferred costs and fair value adjustment	2.5	1.7
Unit-based compensation	25.7	26.8
Loss on long-lived assets, net	4.8	186.9
Gain on acquisition	0.0	(75.3)
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	(133.3)	(0.9)
Deferred income taxes	(0.1)	1.1
Other	0.1	0.0
Changes in operating assets and liabilities	30.5	(123.9)
Net cash provided by operating activities	378.5	277.3
Investing activities
Acquisitions, net of cash acquired (Note 3)	0.0	(604.3)
Purchases of property, plant and equipment	(164.0)	(147.3)
Investments in unconsolidated affiliates	(7.2)	(90.2)
Capital distributions from unconsolidated affiliates	4.4	9.4
Net proceeds from sale of assets, including equity investments	188.2	315.2
Net cash provided by (used in) investing activities	21.4	(517.2)
Financing activities
Proceeds from the issuance of long-term debt	2,058.3	3,072.0
Payments on long-term debt	(2,127.4)	(2,393.1)
Payments on finance leases	(2.0)	(31.3)
Payments for deferred financing costs	(9.2)	(1.8)
Purchase of common units	0.0	(123.7)
Distributions to partners	(206.7)	(196.7)
Distributions to non-controlling partner	(31.0)	(31.0)
Distributions to preferred unitholders	(45.1)	(45.0)
Taxes paid for unit-based compensation vesting	(20.5)	(15.8)
Other	0.0	(0.6)
Net cash provided by (used in) financing activities	(383.6)	233.0
Net change in cash	16.3	(6.9)
Cash at beginning of period	7.5	13.3
Cash at end of period	23.8	6.4
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	(18.4)	19.9
Crestwood Midstream Partners LP
Operating activities
Net income	217.8	(107.4)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	242.5	248.0
Amortization of debt-related deferred costs and fair value adjustment	2.5	1.7
Unit-based compensation	25.7	26.8
Loss on long-lived assets, net	4.8	311.9
Gain on acquisition	0.0	(75.3)
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	(133.3)	(0.9)
Deferred income taxes	0.2	1.2
Other	0.1	0.0
Changes in operating assets and liabilities	31.2	(123.9)
Net cash provided by operating activities	391.5	282.1
Investing activities
Acquisitions, net of cash acquired (Note 3)	0.0	(602.7)
Purchases of property, plant and equipment	(164.0)	(146.6)
Investments in unconsolidated affiliates	(7.2)	(90.2)
Capital distributions from unconsolidated affiliates	4.4	9.4
Net proceeds from sale of assets, including equity investments	188.2	315.2
Net cash provided by (used in) investing activities	21.4	(514.9)
Financing activities
Proceeds from the issuance of long-term debt	2,058.3	3,072.0
Payments on long-term debt	(2,127.4)	(2,393.1)
Payments on finance leases	(2.0)	(31.3)
Payments for deferred financing costs	(9.2)	(1.8)
Contributions from partner	0.0	164.3
Distributions to partners	(264.8)	(537.6)
Distributions to non-controlling partner	(31.0)	(31.0)
Taxes paid for unit-based compensation vesting	(20.5)	(15.8)
Net cash provided by (used in) financing activities	(396.6)	225.7
Net change in cash	16.3	(7.1)
Cash at beginning of period	7.1	12.9
Cash at end of period	23.4	5.8
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$ (18.4)	$ 19.9

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Organization and Business Description

9 Months Ended

Sep. 30, 2023

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).

The accompanying consolidated financial statements and related notes should be read in conjunction with our 2022 Annual Report on Form 10-K filed with the Securities and Exchange Commission (SEC) on February 27, 2023. The financial information as of September 30, 2023 and for the three and nine months ended September 30, 2023 and 2022, is unaudited. The consolidated balance sheets as of December 31, 2022 were derived from the audited balance sheets filed in our 2022 Annual Report on Form 10-K.

Unless otherwise indicated, references in this report to “we,” “us,” “our,” “ours,” “our company,” the “Partnership,” the “Company,” “Crestwood Equity,” “CEQP,” and similar terms refer to either Crestwood Equity Partners LP itself or Crestwood Equity Partners LP and its consolidated subsidiaries, as the context requires. Unless otherwise indicated, references to “Crestwood Midstream” and “CMLP” refer to Crestwood Midstream Partners LP and its consolidated subsidiaries, as the context requires.

Organization

Energy Transfer LP Merger. On November 3, 2023, Crestwood Equity is expected to merge with and into a direct wholly-owned subsidiary of Energy Transfer LP (Energy Transfer) in an all-equity transaction valued at approximately $7.1 billion (the Energy Transfer Merger). On August 16, 2023, Crestwood Equity entered into a merger agreement with Energy Transfer pursuant to which each Crestwood Equity common unit representing limited partner interests in Crestwood Equity issued and outstanding immediately prior to the Energy Transfer Merger will be converted into the right to receive 2.07 common units representing limited partner interests in Energy Transfer. Each preferred unit representing limited partner interests in Crestwood Equity issued and outstanding immediately prior to the Energy Transfer Merger will, at the election of the holder of such preferred unit, be (i) converted into a preferred unit of Energy Transfer that has substantially similar terms, including with respect to economics and structural protections, as the preferred units of Crestwood Equity, (ii) redeemed in exchange for cash, at a price of 108% of the preferred unit price plus accrued and unpaid distributions to the date of such redemption, or (iii) converted into common units, at the then-applicable conversion ratio (one common unit for 10 preferred), subject to the payment of any accrued but unpaid distributions prior to Energy Transfer Merger. In connection with the Energy Transfer Merger and at the direction of Energy Transfer, Crestwood Equity conducted a consent solicitation pursuant to which Crestwood Equity solicited consent from the preferred unitholders to approve an amendment to its Sixth Amended and Restated Agreement of Limited Partnership. Pursuant to the proposed amendment, among other things, (i) the preferred unitholders electing a cash redemption in the Energy Transfer Merger would receive such cash redemption price as increased from 101% to 108% of the preferred unit price; and (ii) the preferred unitholders electing to receive preferred units of Energy Transfer would receive such preferred units of Energy Transfer with terms similar to Energy Transfer’s other outstanding series of preferred units. Crestwood Equity received the consents from the preferred unitholders necessary to approve the proposed amendment and therefore, the proposed amendment will be adopted at the closing of the Energy Transfer Merger.

For more information regarding the merger and the merger agreement, see our Current Report on Form 8-K filed with the SEC on August 16, 2023 and our definitive merger proxy statement on Schedule 14A filed with the SEC on September 29, 2023.

Crestwood Equity Partners LP. CEQP is a publicly-traded Delaware limited partnership, and its common units are listed on the New York Stock Exchange (NYSE) under the ticker symbol “CEQP” and its preferred units are listed on the NYSE under the ticker symbol “CEQP-P.” In connection with the consummation of the Energy Transfer Merger, we requested that the NYSE delist our common and preferred units and, as a result, trading of our common and preferred units will be suspended on November 3, 2023. We also requested that the NYSE file a Form 25 with the SEC notifying the SEC of the delisting of our common and preferred units and the withdrawal of registration of our common and preferred units under Section 12(b) of the Exchange Act. Following the effectiveness of the Form 25, we intend to file with the SEC a Form 15 regarding the termination of registration of our common and preferred units under the Exchange Act and the suspension of reporting obligations with respect to our common and preferred units.

Crestwood Midstream Partners LP. Crestwood Equity owns a 99.9% limited partnership interest in Crestwood Midstream and Crestwood Gas Services GP LLC, 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 North America. 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, 2023

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 in the United States (U.S. 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 U.S. 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 2022 Annual Report on Form 10-K.

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Acquisition and Divestitures

9 Months Ended

Sep. 30, 2023

Business Combination and Asset Acquisition [Abstract]

Acquisition and Divestitures

Acquisitions and Divestitures

Oasis Merger

On February 1, 2022, we completed the merger with Oasis Midstream Partners LP (Oasis Midstream), in an equity and cash transaction which was valued at approximately $1.8 billion (the Oasis Merger). Pursuant to the merger agreement, Oasis Petroleum Inc., now known as Chord Energy Corporation (Chord), 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, Chord received a $10 million cash payment in exchange for its ownership of the general partner of Oasis Midstream.

Sendero and CPJV Acquisitions

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). Additionally, 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). 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. Prior to the CPJV Acquisition, we owned a 50% equity interest in Crestwood Permian, which we accounted for under the equity method of

accounting and we reflected this equity investment in our gathering and processing south segment. As a result of the CPJV Acquisition, we control and own 100% of the equity interests in Crestwood Permian.

Divestitures

Barnett

On July 1, 2022, we sold our assets in the Barnett Shale to EnLink Midstream, LLC for approximately $290 million, and during the nine months ended September 30, 2022, Crestwood Midstream recorded a loss on the sale of approximately $53.3 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 our 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 loss on long-lived assets, net on its consolidated statements of operations.

Marcellus

In October 2022, we sold our assets in the Marcellus Shale to Antero Midstream Corporation for approximately $206 million, and during the three months ended September 30, 2022, we recorded a loss on long-lived assets of approximately $248.2 million for the difference between the historical carrying value of the net assets and liabilities to be sold and the proceeds received from the sale.

Other Divestitures

In August 2023, we sold our transportation assets for approximately $8.0 million, and during the three months ended September 30, 2023, we recorded a loss on long-lived assets of approximately $2.5 million related to the sale of these assets. During the nine months ended September 30, 2022, we recorded a loss on long-lived assets of approximately $7.0 million related to the sale of parts inventory related to our legacy Granite Wash operations.

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Certain Balance Sheet Information

9 Months Ended

Sep. 30, 2023

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,
	2023		2022
CMLP
Accrued expenses	$	56.9	$	66.5
Accrued property taxes	10.5		8.4
Income tax payable	0.7		0.9
Interest payable	64.4		43.2
Accrued additions to property, plant and equipment	16.3		35.6
Operating leases	11.1		10.9
Finance leases	1.7		1.9
Contract liabilities	20.3		11.7
Asset retirement obligations	0.8		0.4
Total CMLP accrued expenses and other liabilities	$	182.7	$	179.5
CEQP
Accrued expenses	0.9		1.2
Income tax payable	—		0.1
Total CEQP accrued expenses and other liabilities	$	183.6	$	180.8

Other Long-Term Liabilities

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

	September 30,		December 31,
	2023		2022
CMLP
Contract liabilities	$	207.4	$	212.3
Intangible liabilities, net	45.5		50.0
Asset retirement obligations	38.5		36.4
Operating leases	15.4		17.4
Other	14.5		14.2
Total CMLP other long-term liabilities	$	321.3	$	330.3
CEQP
Other	2.1		3.1
Total CEQP other long-term liabilities	$	323.4	$	333.4

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Investments in Unconsolidated Affiliates

9 Months Ended

Sep. 30, 2023

Equity Method Investments and Joint Ventures [Abstract]

Investments in Unconsolidated Affiliates

Investments in Unconsolidated Affiliates

Tres Holdings Divestiture

On February 20, 2023, we and Brookfield Infrastructure Group (Brookfield) entered into an agreement with a subsidiary of Enbridge, Inc. to sell each of our respective interests in Tres Palacios Holdings LLC (Tres Holdings) for approximately $335 million, plus working capital adjustments. The sale was completed on April 3, 2023 and we received net cash proceeds of approximately $178 million. We recorded a gain on the sale of approximately $132 million, which is reflected as an increase in our earnings from unconsolidated affiliates in our consolidated statements of operations during the nine months ended September 30, 2023.

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,
	2023		2022		2023		2022		2023		2022
Crestwood Permian Basin LLC(1)	$	74.0	$	76.5	$	1.1	$	0.7	$	2.0	$	0.7
Tres Palacios Holdings LLC(2)	—		39.8		0.1		1.3		133.6		3.2
Powder River Basin Industrial Complex, LLC(3)	3.1		3.2		(0.1)		(0.1)		(0.4)		(0.4)
Crestwood Permian Basin Holdings LLC(4)	—		—		—		1.3		—		8.7
Total	$	77.1	$	119.5	$	1.1	$	3.2	$	135.2	$	12.2

(1)As discussed in Note 3, in July 2022, we acquired the remaining 50% equity interest in Crestwood Permian, whose operations included its 50% equity interest in Crestwood Permian Basin LLC (Crestwood Permian Basin). As of September 30, 2023, our equity in the underlying net assets of Crestwood Permian Basin was less than the carrying value of our investment balance by approximately $2.2 million. During the three and nine months ended September 30, 2023, we recorded amortization of less than $0.1 million and approximately $0.1 million, respectively, related to this basis difference, which is reflected as a decrease in our earnings from unconsolidated affiliates in our consolidated statements of operations, and during both the three and nine months ended September 30, 2022, we recorded amortization of less than $0.1 million related to this basis difference. Our Crestwood Permian Basin investment is included in our gathering and processing south segment.

(2)In April 2023, we sold our equity interest in Tres Holdings and we recorded a gain on the sale of approximately $132 million, which eliminated our $19.9 million historical basis difference between our investment balance and our equity in the underlying net assets of Tres Holdings. During the nine months ended September 30, 2023, we recorded amortization of approximately $0.3 million related to this excess basis, which is reflected as an increase in our earnings from unconsolidated affiliates in our consolidated statements of operations, and during the three and nine months ended September 30, 2022, we recorded amortization of approximately $0.3 million and $0.9 million related to this excess basis. Our Tres Holdings investment was included in our storage and logistics segment. See Tres Holdings Divestiture above for a further discussion of the sale of our Tres Holdings equity investment.

(3)As of September 30, 2023, our equity in the underlying net assets of Powder River Basin Industrial Complex, LLC (PRBIC) approximates the carrying value of our investment balance. Our PRBIC investment is included in our storage and logistics segment.

(4)In July 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. Our Crestwood Permian equity investment was previously included in our gathering and processing south segment. See Note 3 for a further discussion of this acquisition.

Distributions and Contributions

The following table summarizes our distributions from and contributions to our unconsolidated affiliates (in millions):

	Distributions				Contributions
	Nine Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Crestwood Permian Basin	$	6.3	$	2.2	$	1.8	$	—
Tres Holdings	—		4.9		5.1		6.7
PRBIC	—		—		0.3		—
Crestwood Permian	—		13.6		—		83.5
Total	$	6.3	$	20.7	$	7.2	$	90.2

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Risk Management

9 Months Ended

Sep. 30, 2023

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. Our commodity-based derivatives that are settled financially are also reflected in product costs in our consolidated statements of operations. The following table summarizes the increase (decrease) in our product revenues and product costs, net, in our consolidated statements of operations related to our commodity-based derivatives (in millions):

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Product revenues	$	49.1	$	84.7	$	236.0	$	395.7
Product costs, net	$	18.0	$	(45.0)	$	(13.5)	$	6.3

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, 2023		December 31, 2022
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, ethane, butane, heating oil and crude oil (MMBbls)	72.9	78.7	67.2	70.2
Natural gas (Bcf)	11.3	12.8	44.2	48.4

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. 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. For a summary of the fair value of our commodity derivative instruments with credit-risk related contingent features and their associated collateral, see Note 7.

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Fair Value Measurements

9 Months Ended

Sep. 30, 2023

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 — Includes inputs that are observable in active markets for identical assets or liabilities as of the reporting date such as exchange-traded derivatives, listed equities and U.S. government treasury securities.

•Level 2 — Includes inputs that are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Instruments in this category include non-exchange-traded derivatives such as over the counter (OTC) forwards, options and physical exchanges.

•Level 3 — Includes 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, 2023 and December 31, 2022, 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 have been categorized as Level 2.

The following tables summarize the fair value hierarchy of our financial instruments that were reflected in our consolidated balance sheets (in millions):

	September 30, 2023
	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	$	14.5	$	248.6	$	—	$	263.1	$	(213.9)	$	(11.2)	$	38.0
Other investments(2)	2.8		—		—		2.8		—		—		2.8
Total assets at fair value	$	17.3	$	248.6	$	—	$	265.9	$	(213.9)	$	(11.2)	$	40.8
Liabilities
Liabilities from price risk management with credit-risk-related contingent features	$	11.5	$	206.2	$	—	$	217.7	$	(213.9)	$	3.9	$	7.7
Liabilities from price risk management without credit-risk-related contingent features	—		5.5		—		5.5		—		4.4		9.9
Total liabilities at fair value	$	11.5	$	211.7	$	—	$	223.2	$	(213.9)	$	8.3	$	17.6

	December 31, 2022
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting(1)		Collateral/Margin Received or Paid		Fair Value
Assets
Assets from price risk management	$	62.8	$	474.3	$	—	$	537.1	$	(452.1)	$	(12.2)	$	72.8
Other investments(2)	2.6		—		—		2.6		—		—		2.6
Total assets at fair value	$	65.4	$	474.3	$	—	$	539.7	$	(452.1)	$	(12.2)	$	75.4
Liabilities
Liabilities from price risk management with credit-risk-related contingent features	$	65.7	$	420.1	$	—	$	485.8	$	(452.1)	$	(25.6)	$	8.1
Liabilities from price risk management without credit-risk-related contingent features	—		11.9		—		11.9		—		3.9		15.8
Total liabilities at fair value	$	65.7	$	432.0	$	—	$	497.7	$	(452.1)	$	(21.7)	$	23.9

(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, 2023 and December 31, 2022, 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, 2023 and December 31, 2022, primarily due 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, 2023				December 31, 2022
	Carrying  Amount		Fair Value		Carrying  Amount		Fair Value
2025 Senior Notes	$	498.4	$	491.8	$	497.6	$	486.7
2027 Senior Notes	$	596.1	$	576.7	$	595.3	$	556.9
February 2029 Senior Notes	$	693.1	$	674.4	$	692.1	$	642.1
April 2029 Senior Notes(1)	$	473.5	$	464.2	$	476.7	$	450.0
2031 Senior Notes	$	591.6	$	611.5	$	—	$	—

(1)    The carrying amount includes a fair value adjustment we recorded in conjunction with the merger with Oasis Midstream discussed in Note 3. For a further discussion of this fair value adjustment, see Note 8.

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Long-Term Debt

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Long-Term Debt

Long-Term Debt

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

	September 30, 2023		December 31, 2022
CMLP Credit Facility	$	460.0	$	922.3
CPBH Credit Facility	—		206.8
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		450.0
April 2029 Senior Notes fair value adjustment, net(1)	23.5		26.7
2031 Senior Notes	600.0		—
Less: deferred financing costs, net	31.0		27.5
Total long-term debt	$	3,302.5	$	3,378.3

(1)In conjunction with the merger with Oasis Midstream discussed in Note 3, we assumed the April 2029 Senior Notes, and we recorded a fair value adjustment of approximately $30.7 million. We recorded a reduction to our interest and debt expense related to the amortization of the fair value adjustment of approximately $1.1 million and $3.2 million during the three and nine months ended September 30, 2023 and $1.1 million and $2.9 million during the three and nine months ended September 30, 2022.

Credit Facilities

CMLP Credit Facility. Crestwood Midstream’s five-year $1.75 billion revolving credit facility (the CMLP Credit Facility) is available to fund acquisitions, working capital and internal growth projects and for general partnership purposes. Subject to limited exception, the CMLP Credit Facility is guaranteed and secured by substantially all of the equity interests and assets of Crestwood Midstream’s subsidiaries, except for Crestwood Infrastructure Holdings LLC, Crestwood Niobrara LLC, PRBIC and their respective subsidiaries. In January 2023, Crestwood Permian and certain of its subsidiaries were designated as guarantor subsidiaries of Crestwood Midstream’s credit facility and senior notes.

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, in July 2022 we borrowed approximately $631.2 million under the CMLP Credit Facility to fund the Sendero Acquisition.

Under the credit agreement, Crestwood Midstream is required to maintain a net debt to consolidated EBITDA ratio (as defined in the credit agreement) of not more than 5.50 to 1.0, a consolidated EBITDA to consolidated interest expense ratio (as defined in the credit agreement) of not less than 2.50 to 1.0, and a senior secured leverage ratio (as defined in the credit agreement) of not more than 3.50 to 1.0. At September 30, 2023, the net debt to consolidated EBITDA ratio was approximately 4.35 to 1.0, the consolidated EBITDA to consolidated interest expense ratio was approximately 3.65 to 1.0, and the senior secured leverage ratio was 0.61 to 1.0.

At September 30, 2023, Crestwood Midstream had $872.0 million of available capacity under the CMLP Credit Facility considering the most restrictive debt covenants in the credit agreement. At September 30, 2023 and December 31, 2022, outstanding standby letters of credit under the CMLP Credit Facility were $5.7 million and $8.2 million. Borrowings under the CMLP 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 7.67% and 9.75% at September 30, 2023 and 6.28% and 8.50% at December 31, 2022. The weighted-average interest rate on outstanding borrowings as of September 30, 2023 and December 31, 2022 was 7.68% and 6.40%.

CPBH Credit Facility. In conjunction with the acquisition of the remaining 50% equity interest in Crestwood Permian in July 2022, we assumed a credit agreement entered into by CPB Subsidiary Holdings LLC, a wholly-owned subsidiary of Crestwood Permian (the CPBH Credit Facility). In January 2023, we utilized borrowings under the CMLP Credit Facility to repay and terminate the CPBH Credit Facility.

Senior Notes2031 Senior Notes. In January 2023, Crestwood Midstream issued $600 million of 7.375% unsecured senior notes due 2031 (the 2031 Senior Notes). The 2031 Senior Notes will mature on February 1, 2031, and interest is payable semi-annually in arrears on February 1 and August 1 of each year, beginning on August 1, 2023. The net proceeds from this offering of approximately $592.5 million were used to repay borrowings outstanding under the CMLP Credit Facility.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2023

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.

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, 2023. On January 9, 2023, we paid approximately $21.2 million to the Court Registry under protest to mitigate the impact of post-judgement interest. We filed a Notice of Appeal on January 13, 2023 and an Opening Appeal Brief on September 29, 2023. We are unable to predict the ultimate outcome of the appeal related to 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, 2023 and December 31, 2022, we had approximately $8.9 million and $35.0 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 both September 30, 2023 and December 31, 2022, our accrual for environmental matters was less than $1.0 million and our potential exposure related to environmental matters was less than $1.0 million at September 30, 2023.

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, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Self-insurance reserves(1)	$	5.7	$	5.6	$	5.0	$	4.8

(1)At September 30, 2023, CEQP and CMLP classified approximately $3.2 million and $2.7 million, respectively, of these reserves as other long-term liabilities on their consolidated balance sheets.

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, 2023 and December 31, 2022, we have no amounts accrued for these indemnifications.

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Leases

9 Months Ended

Sep. 30, 2023

Leases [Abstract]

Leases

Leases

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

	September 30, 2023		December 31, 2022
Operating Leases
Operating lease right-of-use assets, net	$	23.3	$	24.4
Accrued expenses and other liabilities	$	11.1	$	10.9
Other long-term liabilities	15.4		17.4
Total operating lease liabilities	$	26.5	$	28.3
Finance Leases
Property, plant and equipment	$	9.8	$	13.6
Less: accumulated depreciation	4.9		8.9
Property, plant and equipment, net	$	4.9	$	4.7
Accrued expenses and other liabilities	$	1.7	$	1.9
Other long-term liabilities	3.0		2.7
Total finance lease liabilities	$	4.7	$	4.6

Lease expense. Our operating lease expense, net totaled $3.5 million and $3.4 million for the three months ended September 30, 2023 and 2022 and $10.9 million and $9.2 million for the nine months ended September 30, 2023 and 2022. Our finance lease expense totaled $0.6 million and $0.9 million for the three months ended September 30, 2023 and 2022 and $2.1 million and $2.7 million for the nine months ended September 30, 2023 and 2022.

Other. During March 2022, we exercised an option to purchase crude oil railcars under certain of our finance 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, 2023		December 31, 2022
Operating Leases
Operating lease right-of-use assets, net	$	23.3	$	24.4
Accrued expenses and other liabilities	$	11.1	$	10.9
Other long-term liabilities	15.4		17.4
Total operating lease liabilities	$	26.5	$	28.3
Finance Leases
Property, plant and equipment	$	9.8	$	13.6
Less: accumulated depreciation	4.9		8.9
Property, plant and equipment, net	$	4.9	$	4.7
Accrued expenses and other liabilities	$	1.7	$	1.9
Other long-term liabilities	3.0		2.7
Total finance lease liabilities	$	4.7	$	4.6

Lease expense. Our operating lease expense, net totaled $3.5 million and $3.4 million for the three months ended September 30, 2023 and 2022 and $10.9 million and $9.2 million for the nine months ended September 30, 2023 and 2022. Our finance lease expense totaled $0.6 million and $0.9 million for the three months ended September 30, 2023 and 2022 and $2.1 million and $2.7 million for the nine months ended September 30, 2023 and 2022.

Other. During March 2022, we exercised an option to purchase crude oil railcars under certain of our finance 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, 2023

Statement of Partners' Capital [Abstract]

Partners' Capital

Partners’ Capital and Non-Controlling Partner

Common Units

On February 1, 2022, we completed the merger with Oasis Midstream. Pursuant to the merger agreement, Chord 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 Reserves’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, for approximately $123.7 million. This transaction resulted in CEQP retiring the common units acquired from OMS Holdings LLC.

Distributions

Crestwood Equity

Limited Partners. A summary of CEQP’s limited partner quarterly cash distributions for the nine months ended September 30, 2023 and 2022 is presented below:

Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2023
February 7, 2023	February 14, 2023	$	0.655	$	68.9
May 8, 2023	May 15, 2023	$	0.655	68.9
August 7, 2023	August 14, 2023	$	0.655	68.9
				$	206.7
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

On October 12, 2023, the board of directors of our general partner declared a cash distribution of $0.655 per limited partner unit with respect to the quarter ended September 30, 2023. In addition, the board of directors declared a special cash distribution of $0.003 per limited partner unit in conjunction with the Energy Transfer Merger. The cash distributions were paid on October 31, 2023 to unitholders of record on October 23, 2023.

Preferred Unitholders. During the nine months ended September 30, 2023 and 2022, we paid cash distributions of approximately $45.1 million and $45.0 million to our preferred unitholders. On October 12, 2023, the board of directors of our general partner declared a cash distribution of approximately $15 million with respect to the quarter ended September 30, 2023. In addition, the board of directors declared a special cash distribution of $0.0003 per preferred unit in conjunction with the Energy Transfer Merger. The cash distributions were paid on October 31, 2023 to unitholders of record on October 23, 2023.

Crestwood Midstream

During the nine months ended September 30, 2023 and 2022, Crestwood Midstream paid cash distributions of $264.8 million and $537.6 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, Crestwood Equity contributed the 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, Crestwood Equity contributed the 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 LLC (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 liquidation value each period through net income attributable to non-controlling partner.

In July 2023, we entered into a Fourth Amended and Restated Limited Liability Company Agreement with Jackalope Holdings to modify certain provisions related to the conversion and redemption of the Crestwood Niobrara preferred units. In conjunction with the merger agreement we entered into with Energy Transfer in August 2023 which is further discussed in Note 1, the Crestwood Niobrara preferred units became currently redeemable and as a result, we reflected the Crestwood Niobrara preferred units at their Change of Control Redemption Price (as defined in the agreement) which is equal to 105% of the liquidation value.

The following tables show the change in our non-controlling interest in subsidiary at September 30, 2023 and 2022 (in millions):

Balance at December 31, 2022	$	434.4
Distributions to non-controlling partner	(31.0)
Net income attributable to non-controlling partner(1)	52.6
Balance at September 30, 2023	$	456.0

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

(1)Includes approximately $21.7 million recorded during the three months ended September 30, 2023 to reflect the Crestwood Niobrara preferred units at their maximum redemption value as discussed above.

In October 2023, Crestwood Niobrara paid a cash distribution of approximately $10.3 million to Jackalope Holdings with respect to the quarter ended September 30, 2023.

Other

In February 2023, Crestwood Equity issued 245,929 performance units (the February 2023 Units) under the Crestwood Equity Partners LP 2018 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, 2023, we had total unamortized compensation expense

of approximately $4.5 million related to the February 2023 Units. During the three and nine months ended September 30, 2023, we recognized compensation expense of $0.5 million and $1.9 million related to the February 2023 Units, which is included in general and administrative expenses on our consolidated statements of operations.

During the nine months ended September 30, 2023, 161,278 performance units that were previously issued in 2020 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 217,702 common units during the nine months ended September 30, 2023 related to those performance units.

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Earnings Per Limited Partner Unit

9 Months Ended

Sep. 30, 2023

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 unit-based compensation performance units is calculated using the treasury stock method which considers the impact to net income or loss attributable to Crestwood Equity Partners and limited partner units from the potential issuance of limited partner units.

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, 2023 and 2022 (in millions):

	Three Months Ended		Nine Months Ended
	September 30,		September 30,
	2023	2022	2023	2022
Preferred units(1)	7.1	7.1	7.1	7.1
Crestwood Niobrara’s preferred units(1)	3.8	3.9	—	3.9
Unit-based compensation performance units(1)	0.1	0.1	—	0.2

(1)For additional information regarding the potential conversion/redemption of our preferred units and Crestwood Niobrara’s preferred units to CEQP common units, and additional information regarding our performance units, see our 2022 Annual Report on Form 10-K, Note 1 and Note 11.

The following table shows Crestwood Equity’s common unitholders’ interest in net income (loss) and weighted-average limited partner units used in computing basic and diluted net income (loss) per limited partner unit for the three and nine months ended September 30, 2023 and 2022 (in millions, except for per unit data):

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Common unitholders’ interest in net income (loss)	$	(35.1)	$	(68.3)	$	107.9	$	(57.2)
Diluted net income (loss)	$	(35.1)	$	(68.3)	$	107.9	$	(57.2)
Weighted-average limited partners’ units outstanding - basic	105.2		107.1		105.2		97.1
Dilutive effect of Crestwood Niobrara preferred units	—		—		3.8		—
Dilutive effect of unit-based compensation performance units	—		—		0.1		—
Weighted-average limited partners’ units outstanding - diluted	105.2		107.1		109.1		97.1
Net income (loss) per limited partner unit:
Basic	$	(0.33)	$	(0.64)	$	1.03	$	(0.59)
Diluted	$	(0.33)	$	(0.64)	$	0.99	$	(0.59)

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Segments

9 Months Ended

Sep. 30, 2023

Segment Reporting [Abstract]

Segments

Segments

Our financial statements reflect three operating and reporting segments: (i) gathering and processing north operations; (ii) gathering and processing south operations; and (iii) storage and logistics operations. 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, crude oil gathering services and produced water gathering and disposal services to producers in the Delaware Basin.

•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.

We assess the performance of our operating segments based on EBITDA, which is identified as income (loss) before debt-related costs (interest and debt expense, net), income taxes and depreciation, amortization and accretion expense. Below is a reconciliation of CEQP’s and CMLP’s net income 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,
	2023		2022		2023		2022		2023		2022		2023		2022
Net income (loss)	$	12.1	$	(43.0)	$	205.6	$	18.6	$	21.4	$	(113.0)	$	217.8	$	(107.4)
Add:
Interest and debt expense, net	56.9		47.6		167.9		123.8		56.9		47.6		167.9		123.8
Provision for income taxes	0.2		1.4		1.1		1.7		0.2		1.4		1.0		1.6
Depreciation, amortization and accretion	80.2		86.9		242.7		242.3		80.1		86.8		242.5		248.0
EBITDA	$	149.4	$	92.9	$	617.3	$	386.4	$	158.6	$	22.8	$	629.2	$	266.0

The following tables summarize CEQP’s and CMLP’s reportable segment data for the three and nine months ended September 30, 2023 and 2022 (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 2022 Annual Report on Form 10-K. Included in earnings from unconsolidated affiliates, net reflected in the tables below was approximately $1.3 million and $2.5 million of our proportionate share of net interest income, income taxes, depreciation and amortization expense and gains on long-lived assets, net recorded by our equity investments for the three months ended September 30, 2023 and 2022 and $5.4 million and $12.0 million for the nine months ended September 30, 2023 and 2022.

Segment EBITDA Information

	Three Months Ended September 30, 2023
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	262.8	$	123.0	$	753.6	$	—	$	1,139.4
Intersegment revenues, net	70.9		52.5		(123.4)		—		—
Costs of product/services sold	158.4		121.1		622.1		—		901.6
Operations and maintenance expense	29.9		14.9		12.1		—		56.9
General and administrative expense	—		—		—		20.8		20.8
Loss on long-lived assets, net	—		—		(2.6)		—		(2.6)
Earnings from unconsolidated affiliates, net	—		1.1		—		—		1.1
Crestwood Midstream EBITDA	$	145.4	$	40.6	$	(6.6)	$	(20.8)	$	158.6
Crestwood Equity
General and administrative expense	—		—		—		9.4		9.4
Other income, net	—		—		—		0.2		0.2
Crestwood Equity EBITDA	$	145.4	$	40.6	$	(6.6)	$	(30.0)	$	149.4

	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(1)	—		71.7		—		—		71.7
Crestwood Equity EBITDA	$	157.2	$	(47.3)	$	16.9	$	(33.9)	$	92.9

(1)Represents the gain on the sale of our Barnett operations recorded by CEQP. For a further discussion of this transaction, see Note 3.

	Nine Months Ended September 30, 2023
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	717.1	$	373.3	$	2,333.3	$	—	$	3,423.7
Intersegment revenues, net	231.0		119.2		(350.2)		—		—
Costs of product/services sold	447.7		329.8		1,906.1		—		2,683.6
Operations and maintenance expense	85.6		45.2		35.9		—		166.7
General and administrative expense	—		—		—		74.6		74.6
Gain (loss) on long-lived assets, net	0.1		(2.7)		(2.6)		0.4		(4.8)
Earnings from unconsolidated affiliates, net(1)	—		2.0		133.2		—		135.2
Crestwood Midstream EBITDA	$	414.9	$	116.8	$	171.7	$	(74.2)	$	629.2
Crestwood Equity
General and administrative expense	—		—		—		12.2		12.2
Other income, net	—		—		—		0.3		0.3
Crestwood Equity EBITDA	$	414.9	$	116.8	$	171.7	$	(86.1)	$	617.3

(1)In April 2023, we sold our equity interest in Tres Holdings which is reflected in our storage and logistics segment. During the nine months ended September 30, 2023, we recorded a gain on the sale of approximately $132 million, which is reflected as an increase in our earnings from unconsolidated affiliates.

	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 legacy assets in the Barnett Shale and a gain on long-lived assets of approximately $72 million recorded by CEQP related to the sale. For a further discussion of this transaction, see Note 3.

Other Segment Information

	CEQP				CMLP
	September 30, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Total Assets
Gathering and Processing North	$	3,921.3	$	4,003.6	$	3,921.3	$	4,003.6
Gathering and Processing South	1,452.4		1,473.0		1,452.4		1,473.0
Storage and Logistics	946.1		1,057.6		946.1		1,057.6
Corporate	40.0		32.8		34.4		27.2
Total assets	$	6,359.8	$	6,567.0	$	6,354.2	$	6,561.4

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Revenues

9 Months Ended

Sep. 30, 2023

Revenue Recognition [Abstract]

Revenues

Revenues

Contract Assets and Contract Liabilities

Our contract assets and contract liabilities are reported in a net position on a contract-by-contract basis at the end of each reporting period. Our receivables related to our revenue contracts accounted for under Accounting Standards Update 2014-09, Revenue from Contracts with Customers (Topic 606) totaled $336.5 million and $368.2 million at September 30, 2023 and December 31, 2022, 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 14 years.

The following table summarizes our contract assets and contract liabilities (in millions):

	September 30, 2023		December 31, 2022
Contract assets (non-current)	$	6.8	$	5.4
Contract liabilities (current)(1)	$	20.3	$	11.7
Contract liabilities (non-current)(1)	$	207.4	$	212.3

(1)During the three and nine months ended September 30, 2023, we recognized revenues of approximately $4.5 million and $14.9 million that were previously included in contract liabilities at December 31, 2022. The remaining change in our contract liabilities during the three and nine months ended September 30, 2023 is 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, 2023 (in millions):

Remainder of 2023	$	16.5
2024	46.4
2025	6.5
2026	4.9
2027	2.1
Thereafter	1.1
Total	$	77.5

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, 2023 and 2022 (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, 2023
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	32.2	$	4.8	$	—	$	—	$	37.0
Crude oil	16.9		1.9		—		—		18.8
Water	51.0		8.4		—		—		59.4
Processing
Natural gas	20.0		6.9		—		—		26.9
Storage
Crude oil	0.6		—		—		—		0.6
NGLs	—		—		2.1		—		2.1
Pipeline
Crude oil	1.4		0.1		0.6		—		2.1
NGLs	—		6.8		0.2		(6.8)		0.2
Transportation
NGLs	—		—		2.2		—		2.2
Rail Loading
Crude oil	—		—		0.2		—		0.2
Product Sales
Natural gas	27.4		47.5		78.2		(70.1)		83.0
Crude oil	139.4		0.8		352.2		(15.0)		477.4
NGLs	42.8		98.8		268.4		(31.3)		378.7
Water	1.0		—		—		—		1.0
Other	0.5		—		0.1		(0.2)		0.4
Total Topic 606 revenues	333.2		176.0		704.2		(123.4)		1,090.0
Non-Topic 606 revenues	0.5		(0.5)		49.4		—		49.4
Total revenues	$	333.7	$	175.5	$	753.6	$	(123.4)	$	1,139.4

	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	1.5		0.1		0.6		—		2.2
NGLs	—		5.2		0.1		(5.2)		0.1
Transportation
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

	Nine Months Ended September 30, 2023
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	95.5	$	13.6	$	—	$	—	$	109.1
Crude oil	46.3		6.0		—		—		52.3
Water	139.9		25.2		—		—		165.1
Processing
Natural gas	56.6		19.6		—		—		76.2
Storage
Crude oil	1.7		—		0.1		(0.2)		1.6
NGLs	—		—		6.4		—		6.4
Pipeline
Crude oil	3.7		0.4		1.5		—		5.6
NGLs	—		17.7		0.3		(17.7)		0.3
Transportation
NGLs	—		—		12.4		—		12.4
Rail Loading
Crude oil	—		—		0.6		—		0.6
Product Sales
Natural gas	95.1		113.6		211.9		(182.9)		237.7
Crude oil	377.2		1.1		954.4		(57.7)		1,275.0
NGLs	126.5		296.9		907.8		(91.3)		1,239.9
Water	2.9		—		—		—		2.9
Other	1.1		—		1.0		(0.4)		1.7
Total Topic 606 revenues	946.5		494.1		2,096.4		(350.2)		3,186.8
Non-Topic 606 revenues	1.6		(1.6)		236.9		—		236.9
Total revenues	$	948.1	$	492.5	$	2,333.3	$	(350.2)	$	3,423.7

	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	4.2		0.5		1.5		(0.1)		6.1
NGLs	—		5.2		0.2		(5.2)		0.2
Transportation
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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Related Party Transactions

9 Months Ended

Sep. 30, 2023

Related Party Transactions [Abstract]

Related Party Transactions

Related Party TransactionsWe 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. For a further description of our related party agreements, see our 2022 Annual Report on Form 10-K. During the nine months ended September 30, 2023, we paid approximately $1.0 million of capital expenditures to Applied Consultants, Inc., an affiliate of First Reserve.

The following table shows transactions with our affiliates which are reflected in our consolidated statements of operations (in millions).

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Revenues at CEQP and CMLP(1)	$	—	$	140.8	$	—	$	372.7
Costs of product/services sold at CEQP and CMLP(2)	$	—	$	51.3	$	0.5	$	232.9
Operations and maintenance expenses at CEQP and CMLP(3)	$	1.0	$	2.6	$	4.6	$	12.4
General and administrative expenses charged by CEQP to CMLP, net(4)	$	5.4	$	8.5	$	22.4	$	23.5
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; (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 provided to a subsidiary of Chord; (iii) $0.3 million and $3.9 million during the three and nine months ended September 30, 2022 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) $0.3 million during the nine months ended September 30, 2023 and $0.3 million and $1.7 million during the three and nine months ended September 30, 2022 primarily related to purchases of natural gas from a subsidiary of Tres Holdings; (ii) $0.2 million during the nine months ended September 30, 2023 and $0.3 million during both the three and nine months ended September 30, 2022 related to gathering services under agreements with Crestwood Permian Basin; (iii) $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; and (iv) $9.2 million and $116.8 million during the three and nine months ended September 30, 2022 related to purchases of natural gas and NGLs from a subsidiary of Crestwood Permian.

(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 nine months ended September 30, 2023, we charged $1.5 million to Tres Holdings and during the three and nine months ended September 30, 2023, we charged $1.0 million and $3.1 million to Crestwood Permian Basin. 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.

(4)Includes $6.5 million and $25.7 million of unit-based compensation allocated from CEQP to CMLP during the three and nine months ended September 30, 2023 and $9.6 million and $26.8 million during the three and nine months ended September 30, 2022. 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, 2023 and $1.1 million and $3.3 million during the three and nine months ended September 30, 2022.

(5)Represents general and administrative expenses related to a transition services agreement with Chord.

The following table shows accounts receivable and accounts payable from our affiliates (in millions):

	September 30, 2023		December 31, 2022
Accounts receivable at CEQP and CMLP	$	0.4	$	1.6
Accounts payable at CEQP and CMLP	$	0.1	$	3.0

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Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Pay vs Performance Disclosure
Net income (loss) attributable to parent	$ (20.0)	$ (53.3)	$ 153.0	$ (12.2)

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Insider Trading Arrangements	3 Months Ended
	Sep. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

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

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

Significant Accounting Policies

Significant Accounting Policies

There were no material changes in our significant accounting policies from those described in our 2022 Annual Report on Form 10-K.

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Certain Balance Sheet Information (Tables)

9 Months Ended

Sep. 30, 2023

Balance Sheet Related Disclosures [Abstract]

Schedule of Accrued Liabilities

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

	September 30,		December 31,
	2023		2022
CMLP
Accrued expenses	$	56.9	$	66.5
Accrued property taxes	10.5		8.4
Income tax payable	0.7		0.9
Interest payable	64.4		43.2
Accrued additions to property, plant and equipment	16.3		35.6
Operating leases	11.1		10.9
Finance leases	1.7		1.9
Contract liabilities	20.3		11.7
Asset retirement obligations	0.8		0.4
Total CMLP accrued expenses and other liabilities	$	182.7	$	179.5
CEQP
Accrued expenses	0.9		1.2
Income tax payable	—		0.1
Total CEQP accrued expenses and other liabilities	$	183.6	$	180.8

Schedule of Other Long-Term Liabilities

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

	September 30,		December 31,
	2023		2022
CMLP
Contract liabilities	$	207.4	$	212.3
Intangible liabilities, net	45.5		50.0
Asset retirement obligations	38.5		36.4
Operating leases	15.4		17.4
Other	14.5		14.2
Total CMLP other long-term liabilities	$	321.3	$	330.3
CEQP
Other	2.1		3.1
Total CEQP other long-term liabilities	$	323.4	$	333.4

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Investments in Unconsolidated Affiliates (Tables)

9 Months Ended

Sep. 30, 2023

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,
	2023		2022		2023		2022		2023		2022
Crestwood Permian Basin LLC(1)	$	74.0	$	76.5	$	1.1	$	0.7	$	2.0	$	0.7
Tres Palacios Holdings LLC(2)	—		39.8		0.1		1.3		133.6		3.2
Powder River Basin Industrial Complex, LLC(3)	3.1		3.2		(0.1)		(0.1)		(0.4)		(0.4)
Crestwood Permian Basin Holdings LLC(4)	—		—		—		1.3		—		8.7
Total	$	77.1	$	119.5	$	1.1	$	3.2	$	135.2	$	12.2

(1)As discussed in Note 3, in July 2022, we acquired the remaining 50% equity interest in Crestwood Permian, whose operations included its 50% equity interest in Crestwood Permian Basin LLC (Crestwood Permian Basin). As of September 30, 2023, our equity in the underlying net assets of Crestwood Permian Basin was less than the carrying value of our investment balance by approximately $2.2 million. During the three and nine months ended September 30, 2023, we recorded amortization of less than $0.1 million and approximately $0.1 million, respectively, related to this basis difference, which is reflected as a decrease in our earnings from unconsolidated affiliates in our consolidated statements of operations, and during both the three and nine months ended September 30, 2022, we recorded amortization of less than $0.1 million related to this basis difference. Our Crestwood Permian Basin investment is included in our gathering and processing south segment.

(2)In April 2023, we sold our equity interest in Tres Holdings and we recorded a gain on the sale of approximately $132 million, which eliminated our $19.9 million historical basis difference between our investment balance and our equity in the underlying net assets of Tres Holdings. During the nine months ended September 30, 2023, we recorded amortization of approximately $0.3 million related to this excess basis, which is reflected as an increase in our earnings from unconsolidated affiliates in our consolidated statements of operations, and during the three and nine months ended September 30, 2022, we recorded amortization of approximately $0.3 million and $0.9 million related to this excess basis. Our Tres Holdings investment was included in our storage and logistics segment. See Tres Holdings Divestiture above for a further discussion of the sale of our Tres Holdings equity investment.

(3)As of September 30, 2023, our equity in the underlying net assets of Powder River Basin Industrial Complex, LLC (PRBIC) approximates the carrying value of our investment balance. Our PRBIC investment is included in our storage and logistics segment.

(4)In July 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. Our Crestwood Permian equity investment was previously included in our gathering and processing south segment. See Note 3 for a further discussion of this acquisition.

The following table summarizes our distributions from and contributions to our unconsolidated affiliates (in millions):

	Distributions				Contributions
	Nine Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Crestwood Permian Basin	$	6.3	$	2.2	$	1.8	$	—
Tres Holdings	—		4.9		5.1		6.7
PRBIC	—		—		0.3		—
Crestwood Permian	—		13.6		—		83.5
Total	$	6.3	$	20.7	$	7.2	$	90.2

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Risk Management (Tables)

9 Months Ended

Sep. 30, 2023

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

Summary of Commodity-Based Derivatives

The following table summarizes the increase (decrease) in our product revenues and product costs, net, in our consolidated statements of operations related to our commodity-based derivatives (in millions):

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Product revenues	$	49.1	$	84.7	$	236.0	$	395.7
Product costs, net	$	18.0	$	(45.0)	$	(13.5)	$	6.3

Notional Amounts And Terms Of Company's Derivative Financial Instruments

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

	September 30, 2023		December 31, 2022
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, ethane, butane, heating oil and crude oil (MMBbls)	72.9	78.7	67.2	70.2
Natural gas (Bcf)	11.3	12.8	44.2	48.4

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Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

Assets And Liabilities Measured At Fair Value On Recurring Basis

The following tables summarize the fair value hierarchy of our financial instruments that were reflected in our consolidated balance sheets (in millions):

	September 30, 2023
	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	$	14.5	$	248.6	$	—	$	263.1	$	(213.9)	$	(11.2)	$	38.0
Other investments(2)	2.8		—		—		2.8		—		—		2.8
Total assets at fair value	$	17.3	$	248.6	$	—	$	265.9	$	(213.9)	$	(11.2)	$	40.8
Liabilities
Liabilities from price risk management with credit-risk-related contingent features	$	11.5	$	206.2	$	—	$	217.7	$	(213.9)	$	3.9	$	7.7
Liabilities from price risk management without credit-risk-related contingent features	—		5.5		—		5.5		—		4.4		9.9
Total liabilities at fair value	$	11.5	$	211.7	$	—	$	223.2	$	(213.9)	$	8.3	$	17.6

	December 31, 2022
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting(1)		Collateral/Margin Received or Paid		Fair Value
Assets
Assets from price risk management	$	62.8	$	474.3	$	—	$	537.1	$	(452.1)	$	(12.2)	$	72.8
Other investments(2)	2.6		—		—		2.6		—		—		2.6
Total assets at fair value	$	65.4	$	474.3	$	—	$	539.7	$	(452.1)	$	(12.2)	$	75.4
Liabilities
Liabilities from price risk management with credit-risk-related contingent features	$	65.7	$	420.1	$	—	$	485.8	$	(452.1)	$	(25.6)	$	8.1
Liabilities from price risk management without credit-risk-related contingent features	—		11.9		—		11.9		—		3.9		15.8
Total liabilities at fair value	$	65.7	$	432.0	$	—	$	497.7	$	(452.1)	$	(21.7)	$	23.9

(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, 2023				December 31, 2022
	Carrying  Amount		Fair Value		Carrying  Amount		Fair Value
2025 Senior Notes	$	498.4	$	491.8	$	497.6	$	486.7
2027 Senior Notes	$	596.1	$	576.7	$	595.3	$	556.9
February 2029 Senior Notes	$	693.1	$	674.4	$	692.1	$	642.1
April 2029 Senior Notes(1)	$	473.5	$	464.2	$	476.7	$	450.0
2031 Senior Notes	$	591.6	$	611.5	$	—	$	—

(1)    The carrying amount includes a fair value adjustment we recorded in conjunction with the merger with Oasis Midstream discussed in Note 3. For a further discussion of this fair value adjustment, see Note 8.

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Long-Term Debt (Tables)

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Components Of Long-Term Debt

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

	September 30, 2023		December 31, 2022
CMLP Credit Facility	$	460.0	$	922.3
CPBH Credit Facility	—		206.8
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		450.0
April 2029 Senior Notes fair value adjustment, net(1)	23.5		26.7
2031 Senior Notes	600.0		—
Less: deferred financing costs, net	31.0		27.5
Total long-term debt	$	3,302.5	$	3,378.3

(1)In conjunction with the merger with Oasis Midstream discussed in Note 3, we assumed the April 2029 Senior Notes, and we recorded a fair value adjustment of approximately $30.7 million. We recorded a reduction to our interest and debt expense related to the amortization of the fair value adjustment of approximately $1.1 million and $3.2 million during the three and nine months ended September 30, 2023 and $1.1 million and $2.9 million during the three and nine months ended September 30, 2022.

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Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2023

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, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Self-insurance reserves(1)	$	5.7	$	5.6	$	5.0	$	4.8

(1)At September 30, 2023, CEQP and CMLP classified approximately $3.2 million and $2.7 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, 2023

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, 2023		December 31, 2022
Operating Leases
Operating lease right-of-use assets, net	$	23.3	$	24.4
Accrued expenses and other liabilities	$	11.1	$	10.9
Other long-term liabilities	15.4		17.4
Total operating lease liabilities	$	26.5	$	28.3
Finance Leases
Property, plant and equipment	$	9.8	$	13.6
Less: accumulated depreciation	4.9		8.9
Property, plant and equipment, net	$	4.9	$	4.7
Accrued expenses and other liabilities	$	1.7	$	1.9
Other long-term liabilities	3.0		2.7
Total finance lease liabilities	$	4.7	$	4.6

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Partners' Capital (Tables)

9 Months Ended

Sep. 30, 2023

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, 2023 and 2022 is presented below:

Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2023
February 7, 2023	February 14, 2023	$	0.655	$	68.9
May 8, 2023	May 15, 2023	$	0.655	68.9
August 7, 2023	August 14, 2023	$	0.655	68.9
				$	206.7
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

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, 2023 and 2022 (in millions):

Balance at December 31, 2022	$	434.4
Distributions to non-controlling partner	(31.0)
Net income attributable to non-controlling partner(1)	52.6
Balance at September 30, 2023	$	456.0

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

(1)Includes approximately $21.7 million recorded during the three months ended September 30, 2023 to reflect the Crestwood Niobrara preferred units at their maximum redemption value as discussed above.

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Earnings Per Limited Partner Unit (Tables)

9 Months Ended

Sep. 30, 2023

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, 2023 and 2022 (in millions):

	Three Months Ended		Nine Months Ended
	September 30,		September 30,
	2023	2022	2023	2022
Preferred units(1)	7.1	7.1	7.1	7.1
Crestwood Niobrara’s preferred units(1)	3.8	3.9	—	3.9
Unit-based compensation performance units(1)	0.1	0.1	—	0.2

(1)For additional information regarding the potential conversion/redemption of our preferred units and Crestwood Niobrara’s preferred units to CEQP common units, and additional information regarding our performance units, see our 2022 Annual Report on Form 10-K, Note 1 and Note 11.

Schedule of Weighted Average Number of Shares

The following table shows Crestwood Equity’s common unitholders’ interest in net income (loss) and weighted-average limited partner units used in computing basic and diluted net income (loss) per limited partner unit for the three and nine months ended September 30, 2023 and 2022 (in millions, except for per unit data):

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Common unitholders’ interest in net income (loss)	$	(35.1)	$	(68.3)	$	107.9	$	(57.2)
Diluted net income (loss)	$	(35.1)	$	(68.3)	$	107.9	$	(57.2)
Weighted-average limited partners’ units outstanding - basic	105.2		107.1		105.2		97.1
Dilutive effect of Crestwood Niobrara preferred units	—		—		3.8		—
Dilutive effect of unit-based compensation performance units	—		—		0.1		—
Weighted-average limited partners’ units outstanding - diluted	105.2		107.1		109.1		97.1
Net income (loss) per limited partner unit:
Basic	$	(0.33)	$	(0.64)	$	1.03	$	(0.59)
Diluted	$	(0.33)	$	(0.64)	$	0.99	$	(0.59)

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Segments (Tables)

9 Months Ended

Sep. 30, 2023

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 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,
	2023		2022		2023		2022		2023		2022		2023		2022
Net income (loss)	$	12.1	$	(43.0)	$	205.6	$	18.6	$	21.4	$	(113.0)	$	217.8	$	(107.4)
Add:
Interest and debt expense, net	56.9		47.6		167.9		123.8		56.9		47.6		167.9		123.8
Provision for income taxes	0.2		1.4		1.1		1.7		0.2		1.4		1.0		1.6
Depreciation, amortization and accretion	80.2		86.9		242.7		242.3		80.1		86.8		242.5		248.0
EBITDA	$	149.4	$	92.9	$	617.3	$	386.4	$	158.6	$	22.8	$	629.2	$	266.0

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, 2023 and 2022 (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 2022 Annual Report on Form 10-K. Included in earnings from unconsolidated affiliates, net reflected in the tables below was approximately $1.3 million and $2.5 million of our proportionate share of net interest income, income taxes, depreciation and amortization expense and gains on long-lived assets, net recorded by our equity investments for the three months ended September 30, 2023 and 2022 and $5.4 million and $12.0 million for the nine months ended September 30, 2023 and 2022.

Segment EBITDA Information

	Three Months Ended September 30, 2023
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	262.8	$	123.0	$	753.6	$	—	$	1,139.4
Intersegment revenues, net	70.9		52.5		(123.4)		—		—
Costs of product/services sold	158.4		121.1		622.1		—		901.6
Operations and maintenance expense	29.9		14.9		12.1		—		56.9
General and administrative expense	—		—		—		20.8		20.8
Loss on long-lived assets, net	—		—		(2.6)		—		(2.6)
Earnings from unconsolidated affiliates, net	—		1.1		—		—		1.1
Crestwood Midstream EBITDA	$	145.4	$	40.6	$	(6.6)	$	(20.8)	$	158.6
Crestwood Equity
General and administrative expense	—		—		—		9.4		9.4
Other income, net	—		—		—		0.2		0.2
Crestwood Equity EBITDA	$	145.4	$	40.6	$	(6.6)	$	(30.0)	$	149.4

	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(1)	—		71.7		—		—		71.7
Crestwood Equity EBITDA	$	157.2	$	(47.3)	$	16.9	$	(33.9)	$	92.9

(1)Represents the gain on the sale of our Barnett operations recorded by CEQP. For a further discussion of this transaction, see Note 3.

	Nine Months Ended September 30, 2023
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	717.1	$	373.3	$	2,333.3	$	—	$	3,423.7
Intersegment revenues, net	231.0		119.2		(350.2)		—		—
Costs of product/services sold	447.7		329.8		1,906.1		—		2,683.6
Operations and maintenance expense	85.6		45.2		35.9		—		166.7
General and administrative expense	—		—		—		74.6		74.6
Gain (loss) on long-lived assets, net	0.1		(2.7)		(2.6)		0.4		(4.8)
Earnings from unconsolidated affiliates, net(1)	—		2.0		133.2		—		135.2
Crestwood Midstream EBITDA	$	414.9	$	116.8	$	171.7	$	(74.2)	$	629.2
Crestwood Equity
General and administrative expense	—		—		—		12.2		12.2
Other income, net	—		—		—		0.3		0.3
Crestwood Equity EBITDA	$	414.9	$	116.8	$	171.7	$	(86.1)	$	617.3

(1)In April 2023, we sold our equity interest in Tres Holdings which is reflected in our storage and logistics segment. During the nine months ended September 30, 2023, we recorded a gain on the sale of approximately $132 million, which is reflected as an increase in our earnings from unconsolidated affiliates.

	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 legacy assets in the Barnett Shale and a gain on long-lived assets of approximately $72 million recorded by CEQP related to the sale. For a further discussion of this transaction, see Note 3.

Other Segment Information

	CEQP				CMLP
	September 30, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Total Assets
Gathering and Processing North	$	3,921.3	$	4,003.6	$	3,921.3	$	4,003.6
Gathering and Processing South	1,452.4		1,473.0		1,452.4		1,473.0
Storage and Logistics	946.1		1,057.6		946.1		1,057.6
Corporate	40.0		32.8		34.4		27.2
Total assets	$	6,359.8	$	6,567.0	$	6,354.2	$	6,561.4

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Revenue Recognition (Tables)

9 Months Ended

Sep. 30, 2023

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, 2023		December 31, 2022
Contract assets (non-current)	$	6.8	$	5.4
Contract liabilities (current)(1)	$	20.3	$	11.7
Contract liabilities (non-current)(1)	$	207.4	$	212.3

(1)During the three and nine months ended September 30, 2023, we recognized revenues of approximately $4.5 million and $14.9 million that were previously included in contract liabilities at December 31, 2022. The remaining change in our contract liabilities during the three and nine months ended September 30, 2023 is 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, 2023 (in millions):

Remainder of 2023	$	16.5
2024	46.4
2025	6.5
2026	4.9
2027	2.1
Thereafter	1.1
Total	$	77.5

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, 2023 and 2022 (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, 2023
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	32.2	$	4.8	$	—	$	—	$	37.0
Crude oil	16.9		1.9		—		—		18.8
Water	51.0		8.4		—		—		59.4
Processing
Natural gas	20.0		6.9		—		—		26.9
Storage
Crude oil	0.6		—		—		—		0.6
NGLs	—		—		2.1		—		2.1
Pipeline
Crude oil	1.4		0.1		0.6		—		2.1
NGLs	—		6.8		0.2		(6.8)		0.2
Transportation
NGLs	—		—		2.2		—		2.2
Rail Loading
Crude oil	—		—		0.2		—		0.2
Product Sales
Natural gas	27.4		47.5		78.2		(70.1)		83.0
Crude oil	139.4		0.8		352.2		(15.0)		477.4
NGLs	42.8		98.8		268.4		(31.3)		378.7
Water	1.0		—		—		—		1.0
Other	0.5		—		0.1		(0.2)		0.4
Total Topic 606 revenues	333.2		176.0		704.2		(123.4)		1,090.0
Non-Topic 606 revenues	0.5		(0.5)		49.4		—		49.4
Total revenues	$	333.7	$	175.5	$	753.6	$	(123.4)	$	1,139.4

	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	1.5		0.1		0.6		—		2.2
NGLs	—		5.2		0.1		(5.2)		0.1
Transportation
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

	Nine Months Ended September 30, 2023
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues
Gathering
Natural gas	$	95.5	$	13.6	$	—	$	—	$	109.1
Crude oil	46.3		6.0		—		—		52.3
Water	139.9		25.2		—		—		165.1
Processing
Natural gas	56.6		19.6		—		—		76.2
Storage
Crude oil	1.7		—		0.1		(0.2)		1.6
NGLs	—		—		6.4		—		6.4
Pipeline
Crude oil	3.7		0.4		1.5		—		5.6
NGLs	—		17.7		0.3		(17.7)		0.3
Transportation
NGLs	—		—		12.4		—		12.4
Rail Loading
Crude oil	—		—		0.6		—		0.6
Product Sales
Natural gas	95.1		113.6		211.9		(182.9)		237.7
Crude oil	377.2		1.1		954.4		(57.7)		1,275.0
NGLs	126.5		296.9		907.8		(91.3)		1,239.9
Water	2.9		—		—		—		2.9
Other	1.1		—		1.0		(0.4)		1.7
Total Topic 606 revenues	946.5		494.1		2,096.4		(350.2)		3,186.8
Non-Topic 606 revenues	1.6		(1.6)		236.9		—		236.9
Total revenues	$	948.1	$	492.5	$	2,333.3	$	(350.2)	$	3,423.7

	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	4.2		0.5		1.5		(0.1)		6.1
NGLs	—		5.2		0.2		(5.2)		0.2
Transportation
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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Related Party Transactions (Tables)

9 Months Ended

Sep. 30, 2023

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).

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Revenues at CEQP and CMLP(1)	$	—	$	140.8	$	—	$	372.7
Costs of product/services sold at CEQP and CMLP(2)	$	—	$	51.3	$	0.5	$	232.9
Operations and maintenance expenses at CEQP and CMLP(3)	$	1.0	$	2.6	$	4.6	$	12.4
General and administrative expenses charged by CEQP to CMLP, net(4)	$	5.4	$	8.5	$	22.4	$	23.5
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; (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 provided to a subsidiary of Chord; (iii) $0.3 million and $3.9 million during the three and nine months ended September 30, 2022 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) $0.3 million during the nine months ended September 30, 2023 and $0.3 million and $1.7 million during the three and nine months ended September 30, 2022 primarily related to purchases of natural gas from a subsidiary of Tres Holdings; (ii) $0.2 million during the nine months ended September 30, 2023 and $0.3 million during both the three and nine months ended September 30, 2022 related to gathering services under agreements with Crestwood Permian Basin; (iii) $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; and (iv) $9.2 million and $116.8 million during the three and nine months ended September 30, 2022 related to purchases of natural gas and NGLs from a subsidiary of Crestwood Permian.

(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 nine months ended September 30, 2023, we charged $1.5 million to Tres Holdings and during the three and nine months ended September 30, 2023, we charged $1.0 million and $3.1 million to Crestwood Permian Basin. 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.

(4)Includes $6.5 million and $25.7 million of unit-based compensation allocated from CEQP to CMLP during the three and nine months ended September 30, 2023 and $9.6 million and $26.8 million during the three and nine months ended September 30, 2022. 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, 2023 and $1.1 million and $3.3 million during the three and nine months ended September 30, 2022.

(5)Represents general and administrative expenses related to a transition services agreement with Chord.

Schedule of Related Party Receivables and Payables

The following table shows accounts receivable and accounts payable from our affiliates (in millions):

	September 30, 2023		December 31, 2022
Accounts receivable at CEQP and CMLP	$	0.4	$	1.6
Accounts payable at CEQP and CMLP	$	0.1	$	3.0

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Organization and Business Description (Details) $ in Billions				9 Months Ended
	Nov. 03, 2023 USD ($)	Aug. 16, 2023 shares	Feb. 01, 2022 USD ($) shares	Sep. 30, 2023	Nov. 02, 2023
Oasis Midstream Partners LP
Partnership Organization And Basis Of Presentation [Line Items]
Consideration transferred | $			$ 1.8
Oasis Midstream Partners LP | Chord Energy Corporation
Partnership Organization And Basis Of Presentation [Line Items]
Issued shares (in shares) | shares			20,900,000
Energy Transfer LP | Subsequent Event
Partnership Organization And Basis Of Presentation [Line Items]
Preferred Unit Cash Redemption Rate Percentage	108.00%				101.00%
Preferred Stock, Convertible, Conversion Ratio	0.1
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable | $	$ 7.1
Energy Transfer LP | Crestwood Equity Partners LP Common Unitholders
Partnership Organization And Basis Of Presentation [Line Items]
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable, Entity Shares Issued Per Acquiree Share | shares		2.07
Crestwood Midstream Partners LP | Crestwood Equity Partners LP
Partnership Organization And Basis Of Presentation [Line Items]
Partnership interest				99.90%
Crestwood Midstream Partners LP | Crestwood Gas Services GP, LLC
Partnership Organization And Basis Of Presentation [Line Items]
Partnership interest				0.10%

XML

Acquisition and Divestitures (Details) - USD ($) shares in Millions, $ in Millions			1 Months Ended	3 Months Ended		9 Months Ended
	Jul. 11, 2022	Feb. 01, 2022	Aug. 31, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Oct. 31, 2022	Jul. 10, 2022	Jul. 01, 2022	Apr. 30, 2022
Business Acquisition [Line Items]
Gain on acquisition				$ 0.0	$ 75.3	$ 0.0	$ 75.3
Crestwood Permian Basin Holdings LLC
Business Acquisition [Line Items]
Equity interest percentage	50.00%
Crestwood Midstream Partners LP
Business Acquisition [Line Items]
Gain on acquisition				$ 0.0	75.3	$ 0.0	75.3
Crestwood Permian Basin Holdings LLC
Business Acquisition [Line Items]
Ownership percentage									50.00%
Crestwood Permian Basin LLC
Business Acquisition [Line Items]
Ownership percentage	50.00%
Crestwood Permian Basin Holdings LLC | Crestwood Permian Basin LLC
Business Acquisition [Line Items]
Ownership percentage	50.00%
First Reserve Management, L.P. | Crestwood Permian Basin Holdings LLC
Business Acquisition [Line Items]
Equity interest percentage	50.00%
Disposal Group, Disposed of by Sale, Not Discontinued Operations
Business Acquisition [Line Items]
Sale of assets, consideration											$ 24.7
Loss on sale							4.1
Gathering and Processing South | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Barnett Shale Assets
Business Acquisition [Line Items]
Sale of assets, consideration										$ 290.0
Loss on sale							$ 53.3
Gathering and Processing South | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Granite Wash
Business Acquisition [Line Items]
Loss on sale					7.0
Gathering and Processing South | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Marcellus Shale Assets
Business Acquisition [Line Items]
Sale of assets, consideration								$ 206.0
Gathering and Processing South | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Marcellus Shale Assets | Crestwood Midstream Partners LP
Business Acquisition [Line Items]
Loss on sale					(248.2)
Gathering and Processing South | Disposal Group, Not Discontinued Operations | Barnett Shale Assets | Crestwood Equity Partners LP
Business Acquisition [Line Items]
Loss on sale					$ (72.0)
Storage and Logistics | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Transportation Assets
Business Acquisition [Line Items]
Sale of assets, consideration			$ 8.0
Loss on sale			$ 2.5
Oasis Midstream Partners LP
Business Acquisition [Line Items]
Consideration transferred		$ 1,800.0
Cash payment		160.0
Oasis Midstream Partners LP | Chord Energy Corporation
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 Public Unitholders
Business Acquisition [Line Items]
Issued shares (in shares)		12.9
Oasis Midstream Partners LP | Oasis Midstream Partners LP
Business Acquisition [Line Items]
Stock exchanged (in shares)		14.8
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
Crestwood Permian Basin Holdings LLC
Business Acquisition [Line Items]
Gain on acquisition	$ 75.3
Crestwood Permian Basin Holdings LLC | Crestwood Equity Partners LP
Business Acquisition [Line Items]
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, 2023	Dec. 31, 2022
Accrued Expenses and Other Liabilities [Line Items]
Operating leases	$ 11.1	$ 10.9
Finance leases	1.7	1.9
Contract liabilities	20.3	11.7
Total CMLP accrued expenses and other liabilities	183.6	180.8
Contract liabilities	207.4	212.3
Operating leases	15.4	17.4
Other long-term liabilities	323.4	333.4
Crestwood Midstream Partners LP
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	56.9	66.5
Accrued property taxes	10.5	8.4
Income tax payable	0.7	0.9
Interest payable	64.4	43.2
Accrued additions to property, plant and equipment	16.3	35.6
Operating leases	11.1	10.9
Finance leases	1.7	1.9
Contract liabilities	20.3	11.7
Asset retirement obligations	0.8	0.4
Total CMLP accrued expenses and other liabilities	182.7	179.5
Contract liabilities	207.4	212.3
Intangible liabilities, net	45.5	50.0
Operating leases	15.4	17.4
Asset retirement obligations	38.5	36.4
Other long-term liabilities	321.3	330.3
Crestwood Midstream Partners LP | Other
Accrued Expenses and Other Liabilities [Line Items]
Other long-term liabilities	14.5	14.2
Crestwood Equity Partners LP
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	0.9	1.2
Income tax payable	0.0	0.1
Total CMLP accrued expenses and other liabilities	183.6	180.8
Other long-term liabilities	323.4	333.4
Crestwood Equity Partners LP | Other
Accrued Expenses and Other Liabilities [Line Items]
Other long-term liabilities	$ 2.1	$ 3.1

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Investments in Unconsolidated Affiliates (Narrative) (Details) - Tres Palacios Holdings LLC - USD ($) $ in Millions			9 Months Ended
	Apr. 03, 2023	Feb. 20, 2023	Sep. 30, 2023
Schedule of Equity Method Investments [Line Items]
Proceeds from sale	$ 178	$ 335
Disposal Group, Disposed of by Sale, Not Discontinued Operations
Schedule of Equity Method Investments [Line Items]
Gain (loss) on sale	$ 132		$ 132

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Investments in Unconsolidated Affiliates (Net Investments In and Earnings (Loss) from Unconsolidated Affiliates) (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
	Apr. 03, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022	Jul. 11, 2022	Jul. 10, 2022
Schedule of Equity Method Investments [Line Items]
Investment		$ 77.1		$ 77.1		$ 119.5
Earnings from unconsolidated affiliates, net		1.1	$ 3.2	135.2	$ 12.2
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]
Equity interest percentage							50.00%
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investment		0.0		0.0		0.0
Earnings from unconsolidated affiliates, net		0.0	1.3	0.0	8.7
Ownership percentage								50.00%
Crestwood Permian Basin LLC
Schedule of Equity Method Investments [Line Items]
Investment		74.0		74.0		76.5
Earnings from unconsolidated affiliates, net		1.1	0.7	2.0	0.7
Ownership percentage							50.00%
Difference between carrying amount and underlying equity		2.2		2.2
Amortization		0.1	0.1	0.1	0.1
Crestwood Permian Basin LLC | Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage							50.00%
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investment		0.0		0.0		39.8
Earnings from unconsolidated affiliates, net		0.1	1.3	133.6	3.2
Difference between carrying amount and underlying equity	$ 19.9
Amortization			0.3	0.3	0.9
Tres Palacios Holdings LLC | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Schedule of Equity Method Investments [Line Items]
Gain (loss) on sale	$ 132.0			132.0
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Investment		3.1		3.1		$ 3.2
Earnings from unconsolidated affiliates, net		$ (0.1)	$ (0.1)	$ (0.4)	$ (0.4)

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Investments in Unconsolidated Affiliates (Distributions and Contributions) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Schedule of Equity Method Investments [Line Items]
Distributions	$ 6.3	$ 20.7
Contributions	7.2	90.2
Crestwood Permian Basin LLC
Schedule of Equity Method Investments [Line Items]
Distributions	6.3	2.2
Contributions	1.8	0.0
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Distributions	0.0	4.9
Contributions	5.1	6.7
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Distributions	0.0	0.0
Contributions	0.3	0.0
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Distributions	0.0	13.6
Contributions	$ 0.0	$ 83.5

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Risk Management (Risk Management Activities) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Product revenues	$ 49.1	$ 84.7	$ 236.0	$ 395.7
Commodity contract
Derivative Instruments, Gain (Loss) [Line Items]
Product costs, net	$ 18.0	$ (45.0)	$ (13.5)	$ 6.3

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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, 2023 bcf MMBbls	Dec. 31, 2022 bcf MMBbls
Propane, ethane, butane, heating oil and crude oil (MMBbls) | Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount | MMBbls	72.9	67.2
Propane, ethane, butane, heating oil and crude oil (MMBbls) | Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount | MMBbls	78.7	70.2
Natural gas (Bcf) | Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount | bcf	11.3	44.2
Natural gas (Bcf) | Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount | bcf	12.8	48.4

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Risk Management (Narrative) (Details) - Price Risk Contracts Member - Maximum	9 Months Ended
	Sep. 30, 2023
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, 2023	Dec. 31, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	$ 263.1	$ 537.1
Other investments	2.8	2.6
Total assets at fair value	265.9	539.7
Netting agreements	(213.9)	(452.1)
Assets, Collateral/Margin Received or Paid	(11.2)	(12.2)
Assets from price risk management, total	38.0	72.8
Total assets at fair value	40.8	75.4
Collateral Already Posted, Aggregate Fair Value	3.9	25.6
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	223.2	497.7
Netting agreements	(213.9)	(452.1)
Liabilities, Collateral/Margin Received or Paid	8.3	21.7
Gross Liabilities From Price Risk Management With Credit-Risk-Related Contingent Features	217.7	485.8
Aggregate fair value of commodity derivative instruments	7.7	8.1
Liabilities from price risk management without credit-risk-related contingent features	5.5	11.9
Additional Collateral, Aggregate Fair Value	4.4	3.9
Derivative, Net Liability Position, Aggregate Fair Value, Without Credit-Risk Contingent Features	9.9	15.8
Liabilities, Fair Value Disclosure, Total	17.6	23.9
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	14.5	62.8
Other investments	2.8	2.6
Total assets at fair value	17.3	65.4
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	11.5	65.7
Gross Liabilities From Price Risk Management With Credit-Risk-Related Contingent Features	11.5	65.7
Liabilities from price risk management without credit-risk-related contingent features	0.0	0.0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	248.6	474.3
Other investments	0.0	0.0
Total assets at fair value	248.6	474.3
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	211.7	432.0
Gross Liabilities From Price Risk Management With Credit-Risk-Related Contingent Features	206.2	420.1
Liabilities from price risk management without credit-risk-related contingent features	5.5	11.9
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
Total assets at fair value	0.0	0.0
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	0.0	0.0
Gross Liabilities From Price Risk Management With Credit-Risk-Related Contingent Features	0.0	0.0
Liabilities from price risk management without credit-risk-related contingent features	$ 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, 2023	Dec. 31, 2022
2025 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	$ 498.4	$ 497.6
Fair Value	491.8	486.7
2027 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	596.1	595.3
Fair Value	576.7	556.9
February 2029 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	693.1	692.1
Fair Value	674.4	642.1
April 2029 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	473.5	476.7
Fair Value	464.2	450.0
2031 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	591.6	0.0
Fair Value	$ 611.5	$ 0.0

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Long-Term Debt (Components Of Long-Term Debt) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Jan. 31, 2023	Dec. 31, 2022	Feb. 01, 2022
Debt Instrument [Line Items]
Less: deferred financing costs, net	$ 31.0		$ 31.0			$ 27.5
Total debt	3,302.5		3,302.5			3,378.3
April 2029 Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Fair Value Adjustment	23.5		23.5			26.7
Amortization	1.1	$ 1.1	3.2	$ 2.9
April 2029 Senior Notes | Oasis Midstream Partners LP
Debt Instrument [Line Items]
Debt Instrument, Fair Value Adjustment							$ 30.7
Senior Notes | 2025 Senior Notes
Debt Instrument [Line Items]
Senior notes	500.0		500.0			500.0
Senior Notes | 2027 Senior Notes
Debt Instrument [Line Items]
Senior notes	600.0		600.0			600.0
Senior Notes | February 2029 Senior Notes
Debt Instrument [Line Items]
Senior notes	700.0		700.0			700.0
Senior Notes | April 2029 Senior Notes
Debt Instrument [Line Items]
Senior notes	450.0		450.0			450.0
Senior Notes | 2031 Senior Notes
Debt Instrument [Line Items]
Senior notes	600.0		600.0		$ 600.0	0.0
Revolving Credit Facility | Crestwood Midstream Revolver
Debt Instrument [Line Items]
CMLP Credit Facility	460.0		460.0			922.3
Revolving Credit Facility | CPBH Credit Facility
Debt Instrument [Line Items]
CMLP Credit Facility	$ 0.0		$ 0.0			$ 206.8

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Long-Term Debt (Narrative) (Details)			1 Months Ended	9 Months Ended
	Jul. 11, 2022 USD ($)	Feb. 01, 2022 USD ($)	Jan. 31, 2023 USD ($)	Sep. 30, 2023 USD ($)	Dec. 31, 2022 USD ($)	Jul. 31, 2022 USD ($)
Debt Instrument [Line Items]
Debt term				5 years
Senior secured leverage ratio, maximum				3.50
Senior secured leverage ratio				0.61
Oasis Midstream Partners LP
Debt Instrument [Line Items]
Cash payment		$ 160,000,000
Sendero Midstream Partners, LP
Debt Instrument [Line Items]
Cash payment	$ 631,200,000
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				$ 460,000,000.0	$ 922,300,000
Interest coverage ratio minimum				2.50
Total funded debt to consolidated ebitda				4.35
Consolidated EBITDA to consolidated interest expense ratio				3.65
Available capacity				$ 872,000,000
Letters of credit outstanding				$ 5,700,000	$ 8,200,000
Interest rate				7.68%	6.40%
Crestwood Midstream Revolver | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Interest rate				7.67%	6.28%
Crestwood Midstream Revolver | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Interest rate				9.75%	8.50%
Oasis Midstream Partners LP | Revolving Credit Facility
Debt Instrument [Line Items]
CMLP Credit Facility		$ 218,000,000
Oasis Midstream Partners LP | Revolving Credit Facility | Sendero Midstream Partners, LP
Debt Instrument [Line Items]
CMLP Credit Facility						$ 631,200,000
2031 Senior Notes | Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Senior notes				$ 591,600,000	$ 0
Revolving Loan Facility | Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Borrowing capacity				1,750,000,000
Senior Notes | 2031 Senior Notes
Debt Instrument [Line Items]
Senior notes			$ 600,000,000	$ 600,000,000.0	$ 0
Stated percentage			7.375%
Proceeds from debt offering			$ 592,500,000

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Commitments and Contingencies (Narrative) (Details) - USD ($) $ in Millions	Jan. 09, 2023	Oct. 24, 2022	Sep. 30, 2023	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Damages awarded		$ 20.7
Pre-judgement interest award		17.7
Attorney fees and other costs		$ 4.7
Damages paid	$ 21.2
Accrued amounts for outstanding legal matters			$ 8.9	$ 35.0

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Commitments and Contingencies (Environmental Compliance) (Details) - Fort Berthold Indian Reservation - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Site Contingency [Line Items]
Accrual of environmental loss contingencies	$ 1.0	$ 1.0
Minimum
Site Contingency [Line Items]
Potential liability for environmental exposures	$ 1.0

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Commitments and Contingencies (Self Insurance) (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Crestwood Equity Partners LP
Other Commitments [Line Items]
Self-insurance reserves	$ 5.7	$ 5.6
Self-insurance reserves expected to be paid	3.2
Crestwood Midstream Partners LP
Other Commitments [Line Items]
Self-insurance reserves	5.0	$ 4.8
Self-insurance reserves expected to be paid	$ 2.7

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Leases (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022	Apr. 30, 2022
Lessee, Lease, Description [Line Items]
Operating lease right-of-use assets, net	$ 23.3		$ 23.3		$ 24.4
Operating leases	11.1		11.1		10.9
Operating leases	15.4		15.4		17.4
Total operating lease liabilities	26.5		26.5		28.3
Finance Lease, Right-of-Use Asset, before Accumulated Amortization	9.8		9.8		13.6
Property, plant and equipment	5,467.5		5,467.5		5,353.2
Finance Lease, Right-of-Use Asset, Accumulated Amortization	4.9		4.9		8.9
Less: accumulated depreciation	999.6		999.6		822.8
Finance Lease, Right-of-Use Asset, after Accumulated Amortization	4.9		4.9		4.7
Property, plant and equipment, net	4,467.9		4,467.9		4,530.4
Finance leases	1.7		1.7		1.9
Finance Lease, Liability, Noncurrent	3.0		3.0		2.7
Finance Lease, Liability	4.7		4.7		$ 4.6
Operating lease expense	3.5	$ 3.4	10.9	$ 9.2
Finance lease expense	$ 0.6	0.9	$ 2.1	2.7
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	$ 2.6	$ 175.9	$ 4.8	186.9
Disposal Group, Disposed of by Sale, Not Discontinued Operations
Lessee, Lease, Description [Line Items]
Loss on sale				$ 4.1
Sale of assets, consideration						$ 24.7

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Partners' Capital (Schedule of Partners' Capital Account, Distributions) (Details) - USD ($) $ / shares in Units, $ in Millions													9 Months Ended
	Aug. 14, 2023	Aug. 07, 2023	May 15, 2023	May 08, 2023	Feb. 14, 2023	Feb. 07, 2023	Aug. 12, 2022	Aug. 05, 2022	May 13, 2022	May 06, 2022	Feb. 14, 2022	Feb. 07, 2022	Sep. 30, 2023	Sep. 30, 2022
Distribution Made to Limited Partner [Line Items]
Record Date		Aug. 07, 2023		May 08, 2023		Feb. 07, 2023		Aug. 05, 2022		May 06, 2022		Feb. 07, 2022
Payment Date	Aug. 14, 2023		May 15, 2023		Feb. 14, 2023		Aug. 12, 2022		May 13, 2022		Feb. 14, 2022
Per Unit Rate	$ 0.655		$ 0.655		$ 0.655		$ 0.655		$ 0.655		$ 0.625
Distribution Made to Limited Partner, Cash Distributions Paid	$ 68.9		$ 68.9		$ 68.9		$ 71.6		$ 64.2		$ 60.9		$ 206.7	$ 196.7

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Partners' Capital (Components of Net Income (Loss) Attributable to Non-Controlling Interests) (Details) $ in Millions	1 Months Ended
	Oct. 31, 2023 USD ($)
Crestwood Niobrara LLC | Subsequent Event
Distribution Made to Limited Partner [Line Items]
Distributions to non-controlling partner	$ (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
	Oct. 31, 2023	Oct. 23, 2023	Oct. 12, 2023	Aug. 14, 2023	Aug. 07, 2023	May 15, 2023	May 08, 2023	Feb. 14, 2023	Feb. 07, 2023	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	Oct. 31, 2023	Feb. 28, 2023	Sep. 30, 2023	Sep. 30, 2022	Mar. 31, 2022	Sep. 30, 2023	Sep. 30, 2022
Distribution Made to Limited Partner [Line Items]
Payment Date				Aug. 14, 2023		May 15, 2023		Feb. 14, 2023			Aug. 12, 2022			May 13, 2022		Feb. 14, 2022
Record Date					Aug. 07, 2023		May 08, 2023		Feb. 07, 2023			Aug. 05, 2022			May 06, 2022		Feb. 07, 2022
Distributions to preferred unitholders																								$ 45.1	$ 45.0
Distribution Made to Limited Partner, Cash Distributions Paid				$ 68.9		$ 68.9		$ 68.9			$ 71.6			$ 64.2		$ 60.9								$ 206.7	196.7
Partners' Capital Account, Treasury Units, Purchased										$ 123.7
Change of Control Redemption Price Percentage of Liquidation Value																					105.00%			105.00%
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
Crestwood Midstream Partners LP
Distribution Made to Limited Partner [Line Items]
Distribution Made to General Partner, Cash Distributions Paid																								$ 264.8	537.6
Crestwood Permian Basin Holdings LLC
Distribution Made to Limited Partner [Line Items]
Equity interest percentage													50.00%
Crestwood Permian Basin Holdings LLC | First Reserve Management, L.P.
Distribution Made to Limited Partner [Line Items]
Equity interest percentage													50.00%
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]
Partners' Capital Account, Non-Cash Contributions													$ 127.3					1,075.1				127.3	$ 1,075.1
Partners' Capital Account, Contributions													$ 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																								217,702
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
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]
Payment Date	Oct. 31, 2023
Record Date		Oct. 23, 2023
Distributions to preferred unitholders			$ 15.0
Subsequent Event | Crestwood Niobrara LLC
Distribution Made to Limited Partner [Line Items]
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders																			$ 10.3
Cash Distribution | Subsequent Event
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit			$ 0.655
Cash Distribution | Subsequent Event | Energy Transfer LP
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit			0.003
Cash Distribution | Subsequent Event | Preferred Units | Energy Transfer LP
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit			$ 0.0003
Crestwood LTIP
Distribution Made to Limited Partner [Line Items]
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount																					$ 4.5			$ 4.5
Crestwood LTIP | Performance Shares
Distribution Made to Limited Partner [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period																				245,929				161,278
Share-based Payment Arrangement, Noncash Expense																					$ 0.5			$ 1.9
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period																								3 years
Non-Controlling Partners
Distribution Made to Limited Partner [Line Items]
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders																								$ 31.0	$ 31.0

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Partners' Capital (Rollforward of Non-controlling Interest) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance	$ 434.4	$ 434.6
Net income attributable to non-controlling partner(1)	52.6	30.8
Ending balance	456.0	434.4
Crestwood Niobrara LLC
Increase (Decrease) in Temporary Equity [Roll Forward]
Redeemable Noncontrolling Interest, Equity, Redemption Value	21.7
Non-Controlling Partners
Increase (Decrease) in Temporary Equity [Roll Forward]
Distributions to non-controlling partner	$ (31.0)	$ (31.0)

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Earnings Per Limited Partner Unit (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net Income (Loss) Allocated to Limited Partners	$ (35.1)	$ (68.3)	$ 107.9	$ (57.2)
Net Income (Loss) Available to Common Stockholders, Diluted	$ (35.1)	$ (68.3)	$ 107.9	$ (57.2)
Basic (units)	105.2	107.1	105.2	97.1
Dilutive units (units)	0.0	0.0	3.9	0.0
Diluted (units)	105.2	107.1	109.1	97.1
Basic (in dollars per share)	$ (0.33)	$ (0.64)	$ 1.03	$ (0.59)
Diluted (in dollars per share)	$ (0.33)	$ (0.64)	$ 0.99	$ (0.59)
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
Niobrara Preferred Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Dilutive units (units)	0.0	0.0	3.8	0.0
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	0.1	0.0	0.2
Dilutive units (units)	0.0	0.0	0.1	0.0
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	3.8	3.9	0.0	3.9

XML

Segments (Reconciliation of Net Income (Loss) to EBITDA) (Details) $ in Millions		3 Months Ended		9 Months Ended
	Apr. 03, 2023 USD ($)	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) segment	Sep. 30, 2022 USD ($)
Segment Reporting, Other Significant Reconciling Item [Line Items]
Number of Operating Segments | segment				3
Net income		$ 12.1	$ (43.0)	$ 205.6	$ 18.6
Interest and debt expense, net		56.9	47.6	167.9	123.8
Provision for income taxes		0.2	1.4	1.1	1.7
Depreciation, amortization and accretion		80.2	86.9	242.7	242.3
EBITDA		149.4	92.9	617.3	386.4
Gain (loss) on long-lived assets		(2.6)	(175.9)	(4.8)	(186.9)
Tres Palacios Holdings LLC | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Segment Reporting, Other Significant Reconciling Item [Line Items]
Gain (loss) on sale	$ 132.0			132.0
Crestwood Midstream Partners LP
Segment Reporting, Other Significant Reconciling Item [Line Items]
Net income		21.4	(113.0)	217.8	(107.4)
Interest and debt expense, net		56.9	47.6	167.9	123.8
Provision for income taxes		0.2	1.4	1.0	1.6
Depreciation, amortization and accretion		80.1	86.8	242.5	248.0
EBITDA		158.6	22.8	629.2	266.0
Gain (loss) on long-lived assets		$ (2.6)	$ (247.6)	$ (4.8)	$ (311.9)

XML

Segments (Summary Of Segment Information) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Net income	$ 12.1	$ (43.0)	$ 205.6	$ 18.6
Segment Reporting Information, Additional Information [Abstract]
Total revenues	1,139.4	1,566.0	3,423.7	4,597.8
Costs of product/services sold	901.6	1,286.8	2,683.6	3,864.4
Operations and maintenance	56.9	55.0	166.7	144.0
General and administrative	30.2	33.9	86.8	103.8
Gain (loss) on long-lived assets	(2.6)	(175.9)	(4.8)	(186.9)
Gain on acquisition	0.0	75.3	0.0	75.3
Earnings from unconsolidated affiliates, net	1.1	3.2	135.2	12.2
Other income, net	0.2	0.0	0.3	0.2
EBITDA	149.4	92.9	617.3	386.4
Assets	6,359.8		6,359.8		$ 6,567.0
Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Total revenues	(123.4)	(280.0)	(350.2)	(559.0)
Eliminations
Segment Reporting Information, Additional Information [Abstract]
Gain (Loss) on Disposition of Assets				53.0
Gathering and Processing North | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Total revenues	333.7	414.8	948.1	1,208.4
Gathering and Processing South | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Total revenues	175.5	315.2	492.5	381.2
Storage and Logistics | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Total revenues	753.6	1,116.0	2,333.3	3,567.2
Crestwood Midstream Partners LP
Net income	21.4	(113.0)	217.8	(107.4)
Segment Reporting Information, Additional Information [Abstract]
Total revenues	1,139.4	1,566.0	3,423.7	4,597.8
Costs of product/services sold	901.6	1,286.8	2,683.6	3,864.4
Operations and maintenance	56.9	55.0	166.7	144.0
General and administrative	20.8	32.3	74.6	99.0
Gain (loss) on long-lived assets	(2.6)	(247.6)	(4.8)	(311.9)
Gain on acquisition	0.0	75.3	0.0	75.3
Earnings from unconsolidated affiliates, net	1.1	3.2	135.2	12.2
EBITDA	158.6	22.8	629.2	266.0
Assets	6,354.2		6,354.2		6,561.4
Crestwood Midstream Partners LP | Corporate, Non-Segment
Segment Reporting Information, Additional Information [Abstract]
Total 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	20.8	32.3	74.6	99.0
Gain (loss) on long-lived assets	0.0	0.0	0.4	0.0
Gain on acquisition		0.0		0.0
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
EBITDA	(20.8)	(32.3)	(74.2)	(99.0)
Assets	34.4		34.4		27.2
Crestwood Midstream Partners LP | Corporate and Eliminations
Segment Reporting Information, Additional Information [Abstract]
Total 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]
Total revenues	262.8	272.6	717.1	787.2
Costs of product/services sold	158.4	230.2	447.7	686.6
Operations and maintenance	29.9	27.4	85.6	78.6
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	0.0	0.0	0.1	0.0
Gain on acquisition		0.0		0.0
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
EBITDA	145.4	157.2	414.9	443.2
Assets	3,921.3		3,921.3		4,003.6
Crestwood Midstream Partners LP | Gathering and Processing North | Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Total revenues	70.9	142.2	231.0	421.2
Crestwood Midstream Partners LP | Gathering and Processing South | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Total revenues	123.0	177.4	373.3	243.4
Costs of product/services sold	121.1	249.6	329.8	249.6
Operations and maintenance	14.9	14.3	45.2	28.6
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	0.0	(247.6)	(2.7)	(307.8)
Gain on acquisition		75.3		75.3
Earnings from unconsolidated affiliates, net	1.1	2.0	2.0	9.4
EBITDA	40.6	(119.0)	116.8	(120.1)
Assets	1,452.4		1,452.4		1,473.0
Crestwood Midstream Partners LP | Gathering and Processing South | Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Total revenues	52.5	137.8	119.2	137.8
Crestwood Midstream Partners LP | Storage and Logistics | Operating Segments
Segment Reporting Information, Additional Information [Abstract]
Total revenues	753.6	1,116.0	2,333.3	3,567.2
Costs of product/services sold	622.1	807.0	1,906.1	2,928.2
Operations and maintenance	12.1	13.3	35.9	36.8
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	(2.6)	0.0	(2.6)	(4.1)
Gain on acquisition		0.0		0.0
Earnings from unconsolidated affiliates, net	0.0	1.2	133.2	2.8
EBITDA	(6.6)	16.9	171.7	41.9
Assets	946.1		946.1		1,057.6
Crestwood Midstream Partners LP | Storage and Logistics | Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Total revenues	(123.4)	(280.0)	(350.2)	(559.0)
Crestwood Equity Partners LP
Segment Reporting Information, Additional Information [Abstract]
General and administrative	9.4	1.6	12.2	4.8
Elimination of Loss on Long-Lived Assets		71.7		125.0
Other income, net	0.2		0.3	0.2
EBITDA	149.4	92.9	617.3	386.4
Assets	6,359.8		6,359.8		6,567.0
Crestwood Equity Partners LP | Barnett Shale Assets
Segment Reporting Information, Additional Information [Abstract]
Gain (Loss) on Disposition of Assets				72.0
Crestwood Equity Partners LP | Corporate, Non-Segment
Segment Reporting Information, Additional Information [Abstract]
General and administrative	9.4	1.6	12.2	4.8
Elimination of Loss on Long-Lived Assets		0.0		0.0
Other income, net	0.2		0.3	0.2
EBITDA	(30.0)	(33.9)	(86.1)	(103.6)
Assets	40.0		40.0		32.8
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
Elimination of Loss on Long-Lived Assets		0.0		0.0
Other income, net	0.0		0.0	0.0
EBITDA	145.4	157.2	414.9	443.2
Assets	3,921.3		3,921.3		4,003.6
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
Elimination of Loss on Long-Lived Assets		71.7		125.0
Other income, net	0.0		0.0	0.0
EBITDA	40.6	(47.3)	116.8	4.9
Assets	1,452.4		1,452.4		1,473.0
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
Elimination of Loss on Long-Lived Assets		0.0		0.0
Other income, net	0.0		0.0	0.0
EBITDA	(6.6)	$ 16.9	171.7	$ 41.9
Assets	$ 946.1		$ 946.1		$ 1,057.6

XML

Segments (Narrative) (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) segment	Sep. 30, 2022 USD ($)	Jul. 10, 2022
Segment Reporting Information [Line Items]
Interest, taxes, depreciation and amortization included in earnings from equity method investments | $	$ 1.3	$ 2.5	$ 5.4	$ 12.0
Number of Operating Segments | segment			3
Crestwood Permian Basin Holdings LLC
Segment Reporting Information [Line Items]
Ownership percentage					50.00%

XML

Revenues (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Revenue Recognition [Abstract]
ASC 606 accounts receivable	$ 336.5	$ 368.2

XML

Revenues (Contract Assets and Liabilities) (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2023	Dec. 31, 2022
Contract Assets and Contract Liabilities [Line Items]
Contract Assets (Non-current)	$ 6.8	$ 6.8	$ 5.4
Contract liabilities	20.3	20.3	11.7
Contract liabilities	207.4	207.4	$ 212.3
Contract with Customer, Liability, Revenue Recognized	$ 4.5	$ 14.9

XML

Revenues (Disaggregation of Revenue) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Disaggregation of Revenue [Line Items]
Total revenues	$ 1,139.4	$ 1,566.0	$ 3,423.7	$ 4,597.8
Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	37.0	43.5	109.1	149.2
Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	18.8	16.4	52.3	48.2
Water Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	59.4	49.3	165.1	130.7
Natural Gas Processing
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	26.9	25.5	76.2	61.9
Natural Gas Compression
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues		4.7		11.3
Crude Oil Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.6	0.7	1.6	1.9
NGL Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	2.1	2.2	6.4	6.9
Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	2.1	2.2	5.6	6.1
NGL Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.2	0.1	0.3	0.2
NGL Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	2.2	5.0	12.4	16.3
Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.2		0.6	0.4
Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	83.0	296.8	237.7	591.2
Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	477.4	473.9	1,275.0	1,491.3
NGL Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	378.7	557.3	1,239.9	1,676.6
Water Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	1.0	2.1	2.9	5.0
Other revenue
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.4	0.5	1.7	1.4
Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total revenues	(123.4)	(280.0)	(350.2)	(559.0)
Intersegment Eliminations | Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Intersegment Eliminations | Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Intersegment Eliminations | Water Gathering
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Intersegment Eliminations | Natural Gas Processing
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Intersegment Eliminations | Natural Gas Compression
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues		0.0		0.0
Intersegment Eliminations | Crude Oil Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	(0.2)	(0.2)
Intersegment Eliminations | NGL Storage
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Intersegment Eliminations | Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	(0.1)
Intersegment Eliminations | NGL Pipeline
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	(6.8)	(5.2)	(17.7)	(5.2)
Intersegment Eliminations | NGL Transportation
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Intersegment Eliminations | Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0		0.0	0.0
Intersegment Eliminations | Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	(70.1)	(205.6)	(182.9)	(331.2)
Intersegment Eliminations | Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	(15.0)	(9.8)	(57.7)	(33.9)
Intersegment Eliminations | NGL Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	(31.3)	(58.9)	(91.3)	(187.9)
Intersegment Eliminations | Water Product Sales
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Intersegment Eliminations | Other revenue
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	(0.2)	(0.5)	(0.4)	(0.5)
Operating Segments | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total revenues	333.7	414.8	948.1	1,208.4
Operating Segments | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total revenues	175.5	315.2	492.5	381.2
Operating Segments | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total revenues	753.6	1,116.0	2,333.3	3,567.2
Operating Segments | Natural Gas Gathering | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	32.2	33.4	95.5	92.2
Operating Segments | Natural Gas Gathering | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	4.8	10.1	13.6	57.0
Operating Segments | Natural Gas Gathering | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | Crude Oil Gathering | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	16.9	14.7	46.3	43.6
Operating Segments | Crude Oil Gathering | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	1.9	1.7	6.0	4.6
Operating Segments | Crude Oil Gathering | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | Water Gathering | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	51.0	41.8	139.9	117.7
Operating Segments | Water Gathering | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	8.4	7.5	25.2	13.0
Operating Segments | Water Gathering | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | Natural Gas Processing | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	20.0	20.7	56.6	54.8
Operating Segments | Natural Gas Processing | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	6.9	4.8	19.6	7.1
Operating Segments | Natural Gas Processing | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | Natural Gas Compression | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues		0.0		0.0
Operating Segments | Natural Gas Compression | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues		4.7		11.3
Operating Segments | Natural Gas Compression | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues		0.0		0.0
Operating Segments | Crude Oil Storage | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.6	0.6	1.7	1.7
Operating Segments | Crude Oil Storage | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | Crude Oil Storage | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.1	0.1	0.4
Operating Segments | NGL Storage | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | NGL Storage | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | NGL Storage | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	2.1	2.2	6.4	6.9
Operating Segments | Crude Oil Pipeline | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	1.4	1.5	3.7	4.2
Operating Segments | Crude Oil Pipeline | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.1	0.1	0.4	0.5
Operating Segments | Crude Oil Pipeline | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.6	0.6	1.5	1.5
Operating Segments | NGL Pipeline | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | NGL Pipeline | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	6.8	5.2	17.7	5.2
Operating Segments | NGL Pipeline | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.2	0.1	0.3	0.2
Operating Segments | NGL Transportation | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | NGL Transportation | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | NGL Transportation | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	2.2	5.0	12.4	16.3
Operating Segments | Crude Oil Rail Loading | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0		0.0	0.0
Operating Segments | Crude Oil Rail Loading | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0		0.0	0.0
Operating Segments | Crude Oil Rail Loading | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.2		0.6	0.4
Operating Segments | Natural Gas Product Sales | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	27.4	109.6	95.1	269.1
Operating Segments | Natural Gas Product Sales | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	47.5	144.4	113.6	145.3
Operating Segments | Natural Gas Product Sales | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	78.2	248.4	211.9	508.0
Operating Segments | Crude Oil Product Sales | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	139.4	120.9	377.2	394.9
Operating Segments | Crude Oil Product Sales | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.8	0.0	1.1	0.0
Operating Segments | Crude Oil Product Sales | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	352.2	362.8	954.4	1,130.3
Operating Segments | NGL Product Sales | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	42.8	68.3	126.5	222.7
Operating Segments | NGL Product Sales | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	98.8	136.2	296.9	136.2
Operating Segments | NGL Product Sales | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	268.4	411.7	907.8	1,505.6
Operating Segments | Water Product Sales | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	1.0	2.1	2.9	5.0
Operating Segments | Water Product Sales | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | Water Product Sales | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | Other revenue | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.5	0.8	1.1	1.4
Operating Segments | Other revenue | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.0	0.0	0.0	0.0
Operating Segments | Other revenue | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	0.1	0.2	1.0	0.5
Revenue from Contract with Customer
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	1,090.0	1,480.2	3,186.8	4,198.6
Revenue from Contract with Customer | Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	(123.4)	(280.0)	(350.2)	(559.0)
Revenue from Contract with Customer | Operating Segments | Gathering and Processing North
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	333.2	414.4	946.5	1,207.3
Revenue from Contract with Customer | Operating Segments | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	176.0	314.7	494.1	380.2
Revenue from Contract with Customer | Operating Segments | Storage and Logistics
Disaggregation of Revenue [Line Items]
Total Topic 606 revenues	704.2	1,031.1	2,096.4	3,170.1
Product and Service, Other
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	49.4	85.8	236.9	399.2
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	0.5	0.4	1.6	1.1
Product and Service, Other | Operating Segments | Gathering and Processing South
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	(0.5)	0.5	(1.6)	1.0
Product and Service, Other | Operating Segments | Storage and Logistics
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	$ 49.4	$ 84.9	$ 236.9	$ 397.1

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Revenues (Remaining Performance Obligations) (Details) $ in Millions	Sep. 30, 2023 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 77.5
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
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	$ 16.5
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	$ 46.4
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 6.5
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	$ 4.9
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	1 year
Revenue, Remaining Performance Obligation, Amount	$ 2.1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Revenue, Remaining Performance Obligation, Amount	$ 1.1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2037-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	14 years

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Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Related Party Transaction [Line Items]
Purchases of property, plant and equipment			$ 164.0	$ 147.3
Total revenues	$ 1,139.4	$ 1,566.0	3,423.7	4,597.8
Costs of product/services sold	901.6	1,286.8	2,683.6	3,864.4
Operations and maintenance	56.9	55.0	166.7	144.0
General and administrative	30.2	33.9	86.8	103.8
Accounts receivable	350.1		350.1		$ 432.2
Accounts payable	256.9		256.9		305.5
Affiliated Entity
Related Party Transaction [Line Items]
Accounts receivable	0.4		0.4		1.6
Accounts payable	0.1		0.1		3.0
Related Party | Chord Energy Corporation
Related Party Transaction [Line Items]
Costs of product/services sold		41.5		114.1
General and administrative	0.0	0.0	0.0	1.3
Related Party | Crestwood Permian Basin Holdings LLC
Related Party Transaction [Line Items]
Total revenues		0.1		1.3
Costs of product/services sold		9.2		116.8
Related Party | Applied Consultants, Inc.
Related Party Transaction [Line Items]
Purchases of property, plant and equipment			1.0
Related Party | Tres Palacios Holdings LLC
Related Party Transaction [Line Items]
Costs of product/services sold		0.3	0.3	1.7
Related Party | Crestwood Permian Basin LLC
Related Party Transaction [Line Items]
Costs of product/services sold		0.3	0.2	0.3
Related Party | Crestwood Midstream Partners LP
Related Party Transaction [Line Items]
Total revenues	0.0	140.8	0.0	372.7
Costs of product/services sold	0.0	51.3	0.5	232.9
Operations and maintenance	1.0	2.6	4.6	12.4
General and administrative	5.4	8.5	22.4	23.5
Related Party | Product
Related Party Transaction [Line Items]
Total revenues	0.0	83.2	0.0	222.7
Costs of product/services sold	0.0	51.3	0.5	232.9
Related Party | Product | Chord Energy Corporation
Related Party Transaction [Line Items]
Total revenues		83.0		218.9
Related Party | Product | Crestwood Permian Basin Holdings LLC
Related Party Transaction [Line Items]
Total revenues		0.3		3.9
Related Party | Service
Related Party Transaction [Line Items]
Total revenues	0.0	57.6	0.0	150.0
Related Party | Service | Chord Energy Corporation
Related Party Transaction [Line Items]
Total revenues		57.4		148.6
Crestwood Equity Partners LP
Related Party Transaction [Line Items]
General and administrative	9.4	1.6	12.2	4.8
Crestwood Midstream Partners LP
Related Party Transaction [Line Items]
Purchases of property, plant and equipment			164.0	146.6
Total revenues	1,139.4	1,566.0	3,423.7	4,597.8
Costs of product/services sold	901.6	1,286.8	2,683.6	3,864.4
Operations and maintenance	56.9	55.0	166.7	144.0
General and administrative	20.8	32.3	74.6	99.0
Accounts receivable	350.0		350.0		432.2
Accounts payable	256.9		256.9		$ 305.4
Crestwood Midstream Partners LP | Related Party
Related Party Transaction [Line Items]
General and administrative	1.1	1.1	3.3	3.3
Crestwood Midstream Partners LP | Related Party | Product
Related Party Transaction [Line Items]
Total revenues	0.0	83.2	0.0	222.7
Costs of product/services sold	0.0	51.3	0.5	232.9
Crestwood Midstream Partners LP | Related Party | Service
Related Party Transaction [Line Items]
Total revenues	0.0	57.6	0.0	150.0
Crestwood LTIP | Crestwood Midstream Partners LP | Related Party
Related Party Transaction [Line Items]
Share-based Payment Arrangement, Expense	6.5	9.6	25.7	26.8
Tres Palacios Holdings LLC | Related Party
Related Party Transaction [Line Items]
Operations and maintenance		1.2	1.5	3.5
Crestwood Permian Basin Holdings LLC | Related Party
Related Party Transaction [Line Items]
Operations and maintenance		0.4		7.9
Crestwood Permian Basin LLC | Related Party
Related Party Transaction [Line Items]
Operations and maintenance	$ 1.0	$ 1.0	$ 3.1	$ 1.0