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 ~~June 30, 2022~~March 31, 2023


☐			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

☒

☐

Crestwood Midstream Partners LP

Yes

☒

☐

(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

☒

☐

Crestwood Midstream Partners LP

Yes

☒

☐

Table of Contents

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

☐

☒

Crestwood Midstream Partners LP

Yes

☐

☒

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date ~~(July 22, 2022)~~(April 28, 2023).



Crestwood Equity Partners LP						~~109,248,514~~105,259,769
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.

Table of Contents

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			7

Crestwood Midstream Partners LP

Consolidated Balance Sheets			98

Consolidated Statements of Operations			109

Consolidated Statements of Partners’ Capital			1110

Consolidated Statements of Cash Flows			1211

Notes to Consolidated Financial Statements			1412

Note 1. Organization and Business Description			1412

Note 2. Basis of Presentation and Summary of Significant Accounting Policies			1412

Note 3. Acquisition ~~and Divestitures~~			1513

Note 4. Certain Balance Sheet Information			1713

Note 5. Investments in Unconsolidated Affiliates			1814

Note 6. Risk Management			1915

Note 7. Fair Value Measurements			2016

Note 8. Long-Term Debt			2318

Note 9. Commitments and Contingencies			2419

Note 10. Leases			2521

Note 11. Partners’ Capital and Non-Controlling Partner			2621

Note 12. Earnings Per Limited Partner Unit			2723

Note 13. Segments			2824

Note 14. Revenues			3226

Note 15. Related Party Transactions			3628

~~Note 16. Subsequent Events~~			37

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations			3930

Item 3. Quantitative and Qualitative Disclosures About Market Risk			5138

Item 4. Controls and Procedures			5138

Part II – Other Information

Item 1. Legal Proceedings			5240

Item 1A. Risk Factors			5240

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			5240

Item 3. Defaults Upon Senior Securities			5240

Item 4. Mine Safety Disclosures			5240

Item 5. Other Information			5240

Item 6. Exhibits			5341

Signature			5644

Table of Contents

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements

CRESTWOOD EQUITY PARTNERS LP

CONSOLIDATED BALANCE SHEETS

(in millions, except unit information)


		June 30, 2022		December 31, 2021			March 31, 2023		December 31, 2022
		(unaudited)					(unaudited)
Assets	Assets					Assets
Current assets:	Current assets:					Current assets:
Cash	Cash	$	13.8	$	13.3	Cash	$	8.6	$	7.5

Accounts receivable, less allowance for doubtful accounts of $0.5 million and $0.6 million at June 30, 2022 and December 31, 2021		419.6		378.0
Accounts receivable, less allowance for doubtful accounts of $0.4 and $0.5 at March 31, 2023 and December 31, 2022						Accounts receivable, less allowance for doubtful accounts of $0.4 and $0.5 at March 31, 2023 and December 31, 2022	347.7		432.2
Inventory	Inventory	168.3		156.5		Inventory	100.5		122.6
Assets from price risk management activities	Assets from price risk management activities	34.2		42.1		Assets from price risk management activities	31.4		72.8
Assets held for sale, net		217.8		—

Prepaid expenses and other current assets	Prepaid expenses and other current assets	12.1		14.8		Prepaid expenses and other current assets	15.5		18.7
Total current assets	Total current assets	865.8		604.7		Total current assets	503.7		653.8
Property, plant and equipment	Property, plant and equipment	4,712.3		3,771.5		Property, plant and equipment	5,402.6		5,353.2
Less: accumulated depreciation	Less: accumulated depreciation	916.5		992.1		Less: accumulated depreciation	887.3		822.8
Property, plant and equipment, net	Property, plant and equipment, net	3,795.8		2,779.4		Property, plant and equipment, net	4,515.3		4,530.4
Intangible assets	Intangible assets	1,590.1		1,126.1		Intangible assets	1,306.3		1,306.3
Less: accumulated amortization	Less: accumulated amortization	433.5		393.2		Less: accumulated amortization	317.7		300.7
Intangible assets, net	Intangible assets, net	1,156.6		732.9		Intangible assets, net	988.6		1,005.6
Goodwill	Goodwill	194.8		138.6		Goodwill	223.0		223.0
Operating lease right-of-use assets, net	Operating lease right-of-use assets, net	18.8		27.4		Operating lease right-of-use assets, net	24.4		24.4
Investments in unconsolidated affiliates	Investments in unconsolidated affiliates	164.8		155.8		Investments in unconsolidated affiliates	124.3		119.5
Other non-current assets	Other non-current assets	6.2		6.9		Other non-current assets	10.0		10.3
Total assets	Total assets	$	6,202.8	$	4,445.7	Total assets	$	6,389.3	$	6,567.0

Liabilities and capital	Liabilities and capital					Liabilities and capital
Current liabilities:	Current liabilities:					Current liabilities:
Accounts payable	Accounts payable	$	404.1	$	336.5	Accounts payable	$	277.7	$	305.5
Accrued expenses and other liabilities	Accrued expenses and other liabilities	158.6		147.1		Accrued expenses and other liabilities	167.9		180.8
Liabilities from price risk management activities	Liabilities from price risk management activities	82.3		114.6		Liabilities from price risk management activities	13.2		23.9

Current portion of long-term debt		0.2		0.2

Total current liabilities	Total current liabilities	645.2		598.4		Total current liabilities	458.8		510.2
Long-term debt, less current portion	Long-term debt, less current portion	2,929.3		2,052.1		Long-term debt, less current portion	3,314.5		3,378.3

Other long-term liabilities	Other long-term liabilities	268.0		258.7		Other long-term liabilities	325.0		333.4
Deferred income taxes	Deferred income taxes	2.5		2.3		Deferred income taxes	3.4		3.5
Total liabilities	Total liabilities	3,845.0		2,911.5		Total liabilities	4,101.7		4,225.4
Commitments and contingencies (Note 9)	Commitments and contingencies (Note 9)	0		0		Commitments and contingencies (Note 9)
Interest of non-controlling partner in subsidiary	Interest of non-controlling partner in subsidiary	434.4		434.6		Interest of non-controlling partner in subsidiary	434.3		434.4
Crestwood Equity Partners LP partners’ capital (97,969,654 and 62,991,511 common units issued and outstanding at June 30, 2022 and December 31, 2021)		1,311.4		487.6
Preferred units (71,257,445 units issued and outstanding at both June 30, 2022 and December 31, 2021)		612.0		612.0
Partners’ capital:						Partners’ capital:
Crestwood Equity Partners LP partners’ capital (105,286,780 and 104,646,374 common units issued and outstanding at March 31, 2023 and December 31, 2022)						Crestwood Equity Partners LP partners’ capital (105,286,780 and 104,646,374 common units issued and outstanding at March 31, 2023 and December 31, 2022)	1,241.3		1,295.2
Preferred units (71,257,445 units issued and outstanding at both March 31, 2023 and December 31, 2022)						Preferred units (71,257,445 units issued and outstanding at both March 31, 2023 and December 31, 2022)	612.0		612.0
Total partners’ capital	Total partners’ capital	1,923.4		1,099.6		Total partners’ capital	1,853.3		1,907.2
Total liabilities and capital	Total liabilities and capital	$	6,202.8	$	4,445.7	Total liabilities and capital	$	6,389.3	$	6,567.0

See accompanying notes.

Table of Contents


CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF OPERATIONS (in millions, except per unit data) (unaudited)	CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF OPERATIONS (in millions, except per unit data) (unaudited)									CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF OPERATIONS (in millions, except per unit data) (unaudited)
		Three Months Ended				Six Months Ended					Three Months Ended
		June 30,				June 30,					March 31,
		2022		2021		2022		2021				2023		2022
Revenues:	Revenues:									Revenues:
Product revenues	Product revenues	$	1,215.0	$	820.7	$	2,605.5	$	1,751.3	Product revenues		$	1,122.3	$	1,390.5
Product revenues - related party (Note 15)	Product revenues - related party (Note 15)	78.9		12.8		139.5		17.7		Product revenues - related party (Note 15)		—		60.6
Service revenues	Service revenues	98.8		95.7		194.4		192.9		Service revenues		140.8		95.6
Service revenues - related party (Note 15)	Service revenues - related party (Note 15)	55.3		0.4		92.4		0.4		Service revenues - related party (Note 15)		—		37.1
Total revenues	Total revenues	1,448.0		929.6		3,031.8		1,962.3		Total revenues		1,263.1		1,583.8

Costs of product/services sold (exclusive of items shown separately below):	Costs of product/services sold (exclusive of items shown separately below):									Costs of product/services sold (exclusive of items shown separately below):
Product costs	Product costs	1,094.0		768.0		2,384.8		1,535.6		Product costs		991.0		1,290.8
Product costs - related party (Note 15)	Product costs - related party (Note 15)	113.1		25.4		181.6		66.5		Product costs - related party (Note 15)		0.4		68.5
Service costs	Service costs	6.1		3.8		11.2		8.9		Service costs		6.0		5.1
Total costs of products/services sold	Total costs of products/services sold	1,213.2		797.2		2,577.6		1,611.0		Total costs of products/services sold		997.4		1,364.4

Operating expenses and other:	Operating expenses and other:									Operating expenses and other:
Operations and maintenance	Operations and maintenance	46.6		25.8		89.0		58.6		Operations and maintenance		56.6		42.4
General and administrative	General and administrative	26.5		22.8		69.9		41.5		General and administrative		31.6		43.4
Depreciation, amortization and accretion	Depreciation, amortization and accretion	80.6		58.8		155.4		118.0		Depreciation, amortization and accretion		81.4		74.8
(Gain) loss on long-lived assets, net		7.2		(0.3)		11.0		1.1
Loss on long-lived assets, net										Loss on long-lived assets, net		0.4		3.8

		160.9		107.1		325.3		219.2				170.0		164.4
Operating income	Operating income	73.9		25.3		128.9		132.1		Operating income		95.7		55.0
Earnings (loss) from unconsolidated affiliates, net		6.0		(27.1)		9.0		(130.8)
Earnings from unconsolidated affiliates, net										Earnings from unconsolidated affiliates, net		1.7		3.0
Interest and debt expense, net	Interest and debt expense, net	(40.1)		(35.1)		(76.2)		(71.1)		Interest and debt expense, net		(55.6)		(36.1)
Loss on modification/extinguishment of debt		—		(1.2)		—		(6.7)
Other income (expense), net		(0.1)		0.1		0.2		0.1
Income (loss) before income taxes		39.7		(38.0)		61.9		(76.4)

Other income, net										Other income, net		0.1		0.3
Income before income taxes										Income before income taxes		41.9		22.2
Provision for income taxes	Provision for income taxes	(0.3)		(0.1)		(0.3)		—		Provision for income taxes		(0.3)		—
Net income (loss)		39.4		(38.1)		61.6		(76.4)
Net income										Net income		41.6		22.2
Net income attributable to non-controlling partner	Net income attributable to non-controlling partner	10.3		10.3		20.5		20.4		Net income attributable to non-controlling partner		10.2		10.2
Net income (loss) attributable to Crestwood Equity Partners LP		29.1		(48.4)		41.1		(96.8)
Net income attributable to Crestwood Equity Partners LP										Net income attributable to Crestwood Equity Partners LP		31.4		12.0
Net income attributable to preferred units	Net income attributable to preferred units	15.0		15.0		30.0		30.0		Net income attributable to preferred units		15.0		15.0
Net income (loss) attributable to partners	Net income (loss) attributable to partners	$	14.1	$	(63.4)	$	11.1	$	(126.8)	Net income (loss) attributable to partners		$	16.4	$	(3.0)

Net income (loss) per limited partner unit: (Note 12)	Net income (loss) per limited partner unit: (Note 12)									Net income (loss) per limited partner unit: (Note 12)
Basic	Basic	$	0.14	$	(1.00)	$	0.12	$	(1.85)	Basic		$	0.16	$	(0.04)
Diluted	Diluted	$	0.14	$	(1.00)	$	0.11	$	(1.85)	Diluted		$	0.15	$	(0.04)
Weighted-average limited partners’ units outstanding:	Weighted-average limited partners’ units outstanding:									Weighted-average limited partners’ units outstanding:
Basic	Basic	98.0		63.5		92.0		68.4		Basic		105.2		86.0
Dilutive	Dilutive	4.6		—		4.7		—		Dilutive		4.6		—
Diluted	Diluted	102.6		63.5		96.7		68.4		Diluted		109.8		86.0

See accompanying notes.

Table of Contents

CRESTWOOD EQUITY PARTNERS LP

CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL

(in millions)

(unaudited)


		Preferred			Common						Preferred			Common
		Units	Capital		Units	Capital		Total Partners’ Capital			Units	Capital		Units	Capital		Total Partners’ Capital
Balance at December 31, 2021		71.3	$	612.0	63.0	$	487.6	$	1,099.6
Balance at December 31, 2022										Balance at December 31, 2022	71.3	$	612.0	104.6	$	1,295.2	$	1,907.2
Distributions to partners	Distributions to partners	—	(15.0)		—	(60.9)		(75.9)		Distributions to partners	—	(15.0)		—	(68.9)		(83.9)
Issuance of common units (Note 3)		—	—		33.8	930.0		930.0
Unit-based compensation charges		—	—		1.6	13.0		13.0
Taxes paid for unit-based compensation vesting		—	—		(0.5)	(14.9)		(14.9)
Other		—	—		0.1	2.2		2.2
Net income (loss)		—	15.0		—	(3.0)		12.0
Balance at March 31, 2022		71.3	612.0		98.0	1,354.0		1,966.0
Distributions to partners		—	(15.0)		—	(64.2)		(79.2)

Unit-based compensation charges	Unit-based compensation charges	—	—		—	8.6		8.6		Unit-based compensation charges	—	—		1.1	11.8		11.8
Taxes paid for unit-based compensation vesting	Taxes paid for unit-based compensation vesting	—	—		—	(0.7)		(0.7)		Taxes paid for unit-based compensation vesting	—	—		(0.5)	(14.8)		(14.8)
Other	Other	—	—		—	(0.4)		(0.4)		Other	—	—		0.1	1.6		1.6
Net income	Net income	—	15.0		—	14.1		29.1		Net income	—	15.0		—	16.4		31.4
Balance at June 30, 2022		71.3	$	612.0	98.0	$	1,311.4	$	1,923.4
Balance at March 31, 2023										Balance at March 31, 2023	71.3	$	612.0	105.3	$	1,241.3	$	1,853.3

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


	Preferred			Common
	Units	Capital		Units	Capital		Total Partners’ Capital
Balance at December 31, 2021	71.3	$	612.0	63.0	$	487.6	$	1,099.6
Distributions to partners	—	(15.0)		—	(60.9)		(75.9)
Issuance of common units (Note 3)	—	—		33.8	930.0		930.0
Unit-based compensation charges	—	—		1.6	13.0		13.0
Taxes paid for unit-based compensation vesting	—	—		(0.5)	(14.9)		(14.9)
Other	—	—		0.1	2.2		2.2
Net income (loss)	—	15.0		—	(3.0)		12.0
Balance at March 31, 2022	71.3	$	612.0	98.0	$	1,354.0	$	1,966.0

See accompanying notes.

Table of Contents

CRESTWOOD EQUITY PARTNERS LP
CONSOLIDATED STATEMENTS OF CASH FLOWS
(in millions)
(unaudited)

Six Months Ended
June 30,
2022 2021
Operating activities
Net income (loss) $ 61.6 $ (76.4)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion 155.4 118.0
Amortization of debt-related deferred costs and fair value adjustment 1.2 3.4
Unit-based compensation charges 17.2 9.9
Loss on long-lived assets, net 11.0 1.1
Loss on modification/extinguishment of debt — 6.7
(Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received (0.2) 141.1
Deferred income taxes (0.1) (0.1)
Other (0.1) 0.1
Changes in operating assets and liabilities 6.0 89.7
Net cash provided by operating activities 252.0 293.5
Investing activities
Acquisition, net of cash acquired (Note 3)
(145.1) —
Purchases of property, plant and equipment (78.2) (21.3)
Investments in unconsolidated affiliates (15.0) (10.2)
Capital distributions from unconsolidated affiliates 6.2 32.9
Net proceeds from sale of assets 25.7 0.5
Net cash provided by (used in) investing activities (206.4) 1.9
Financing activities
Proceeds from the issuance of long-term debt 1,649.8 2,005.6
Payments on long-term debt (1,470.8) (1,866.8)
Payments on finance leases (30.4) (1.4)
Payments for deferred financing costs (1.7) (11.1)
Payments for Crestwood Holdings Transactions — (275.6)
Distributions to partners (125.1) (85.7)
Distributions to non-controlling partner (20.7) (19.6)
Distributions to preferred unitholders (30.0) (30.0)
Taxes paid for unit-based compensation vesting (15.6) (8.2)
Other (0.6) —
Net cash used in financing activities (45.1) (292.8)
Net change in cash 0.5 2.6
Cash at beginning of period 13.3 14.0
Cash at end of period $ 13.8 $ 16.6

~~Table of Contents~~

~~CRESTWOOD EQUITY PARTNERS LP~~

~~CONSOLIDATED STATEMENTS OF CASH FLOWS (continued)~~

~~(in millions)~~

~~(unaudited)~~

Six Months Ended
June 30,
2022 2021
Supplemental schedule of non-cash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses $ 14.5 $ (29.2)
Acquisition, net of cash acquired:
Current assets $ 63.2 $ —
Property, plant and equipment 1,264.4 —
Intangible assets 464.0 —
Goodwill 56.2 —
Current liabilities (48.2) —
Debt (698.7) —
Change in invested capital of Crestwood Equity Partners LP, net (930.0) —
Other liabilities (25.8) —
Total acquisition, net of cash acquired $ 145.1 $ —


CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF CASH FLOWS (in millions) (unaudited)
	Three Months Ended
	March 31,
	2023		2022
Operating activities
Net income	$	41.6	$	22.2
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	81.4		74.8
Amortization of debt-related deferred costs and fair value adjustment	0.8		0.8
Unit-based compensation charges	10.0		8.6
Loss on long-lived assets, net	0.4		3.8



Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	(1.4)		(0.4)
Deferred income taxes	—		(0.1)
Other	—		(0.1)
Changes in operating assets and liabilities	113.1		112.9





Net cash provided by operating activities	245.9		222.5
Investing activities
Acquisition, net of cash acquired (Note 3)	—		(145.1)
Purchases of property, plant and equipment	(67.3)		(26.4)
Investments in unconsolidated affiliates	(5.1)		(14.5)
Capital distributions from unconsolidated affiliates	1.7		5.9
Net proceeds from sale of assets	0.3		0.4

Net cash used in investing activities	(70.4)		(179.7)
Financing activities
Proceeds from the issuance of long-term debt	1,153.7		919.1
Payments on long-term debt	(1,209.2)		(859.1)
Payments on finance leases	(0.8)		(0.8)
Payments for deferred financing costs	(9.1)		(1.7)






Distributions to partners	(68.9)		(60.9)
Distributions to non-controlling partner	(10.3)		(10.3)
Distributions to preferred unitholders	(15.0)		(15.0)

Taxes paid for unit-based compensation vesting	(14.8)		(14.9)
Other	—		(0.6)
Net cash used in financing activities	(174.4)		(44.2)
Net change in cash	1.1		(1.4)
Cash at beginning of period	7.5		13.3
Cash at end of period	$	8.6	$	11.9
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$	(16.8)	$	3.8

See accompanying notes.

Table of Contents

CRESTWOOD MIDSTREAM PARTNERS LP

CONSOLIDATED BALANCE SHEETS

(in millions)


		June 30, 2022		December 31, 2021			March 31, 2023		December 31, 2022
		(unaudited)					(unaudited)
Assets	Assets					Assets
Current assets:	Current assets:					Current assets:
Cash	Cash	$	13.3	$	12.9	Cash	$	8.3	$	7.1

Accounts receivable, less allowance for doubtful accounts of $0.5 million and $0.6 million at June 30, 2022 and December 31, 2021		419.6		378.0
Accounts receivable, less allowance for doubtful accounts of $0.4 and $0.5 at March 31, 2023 and December 31, 2022						Accounts receivable, less allowance for doubtful accounts of $0.4 and $0.5 at March 31, 2023 and December 31, 2022	347.6		432.2
Inventory	Inventory	168.3		156.5		Inventory	100.5		122.6
Assets from price risk management activities	Assets from price risk management activities	34.2		42.1		Assets from price risk management activities	31.4		72.8
Assets held for sale, net		289.5		—

Prepaid expenses and other current assets	Prepaid expenses and other current assets	12.1		14.4		Prepaid expenses and other current assets	15.5		18.7
Total current assets	Total current assets	937.0		603.9		Total current assets	503.3		653.4
Property, plant and equipment	Property, plant and equipment	4,709.1		4,100.8		Property, plant and equipment	5,399.3		5,350.0
Less: accumulated depreciation	Less: accumulated depreciation	916.4		1,193.0		Less: accumulated depreciation	887.0		822.6
Property, plant and equipment, net	Property, plant and equipment, net	3,792.7		2,907.8		Property, plant and equipment, net	4,512.3		4,527.4
Intangible assets	Intangible assets	1,590.1		1,126.1		Intangible assets	1,306.3		1,306.3
Less: accumulated amortization	Less: accumulated amortization	433.5		393.2		Less: accumulated amortization	317.7		300.7
Intangible assets, net	Intangible assets, net	1,156.6		732.9		Intangible assets, net	988.6		1,005.6
Goodwill	Goodwill	194.8		138.6		Goodwill	223.0		223.0
Operating lease right-of-use assets, net	Operating lease right-of-use assets, net	18.8		27.4		Operating lease right-of-use assets, net	24.4		24.4
Investments in unconsolidated affiliates	Investments in unconsolidated affiliates	164.8		155.8		Investments in unconsolidated affiliates	124.3		119.5
Other non-current assets	Other non-current assets	4.0		4.8		Other non-current assets	7.9		8.1
Total assets	Total assets	$	6,268.7	$	4,571.2	Total assets	$	6,383.8	$	6,561.4
Liabilities and capital	Liabilities and capital					Liabilities and capital
Current liabilities:	Current liabilities:					Current liabilities:
Accounts payable	Accounts payable	$	404.1	$	336.4	Accounts payable	$	277.7	$	305.4
Accrued expenses and other liabilities	Accrued expenses and other liabilities	157.3		146.1		Accrued expenses and other liabilities	167.0		179.5
Liabilities from price risk management activities	Liabilities from price risk management activities	82.3		114.6		Liabilities from price risk management activities	13.2		23.9

Current portion of long-term debt		0.2		0.2

Total current liabilities	Total current liabilities	643.9		597.3		Total current liabilities	457.9		508.8
Long-term debt, less current portion	Long-term debt, less current portion	2,929.3		2,052.1		Long-term debt, less current portion	3,314.5		3,378.3

Other long-term liabilities	Other long-term liabilities	266.2		254.1		Other long-term liabilities	323.5		330.3
Deferred income taxes	Deferred income taxes	1.1		0.8		Deferred income taxes	2.4		2.3
Total liabilities	Total liabilities	3,840.5		2,904.3		Total liabilities	4,098.3		4,219.7
Commitments and contingencies (Note 9)	Commitments and contingencies (Note 9)	0		0		Commitments and contingencies (Note 9)
Interest of non-controlling partner in subsidiary	Interest of non-controlling partner in subsidiary	434.4		434.6		Interest of non-controlling partner in subsidiary	434.3		434.4
Partners’ capital	Partners’ capital	1,993.8		1,232.3		Partners’ capital	1,851.2		1,907.3

Total liabilities and capital	Total liabilities and capital	$	6,268.7	$	4,571.2	Total liabilities and capital	$	6,383.8	$	6,561.4

See accompanying notes.

Table of Contents

CRESTWOOD MIDSTREAM PARTNERS LP

CONSOLIDATED STATEMENTS OF OPERATIONS

(in millions)

(unaudited)


		Three Months Ended				Six Months Ended					Three Months Ended
		June 30,				June 30,					March 31,
		2022		2021		2022		2021				2023		2022
Revenues:	Revenues:									Revenues:
Product revenues	Product revenues	$	1,215.0	$	820.7	$	2,605.5	$	1,751.3	Product revenues		$	1,122.3	$	1,390.5
Product revenues - related party (Note 15)	Product revenues - related party (Note 15)	78.9		12.8		139.5		17.7		Product revenues - related party (Note 15)		—		60.6
Service revenues	Service revenues	98.8		95.7		194.4		192.9		Service revenues		140.8		95.6
Service revenues - related party (Note 15)	Service revenues - related party (Note 15)	55.3		0.4		92.4		0.4		Service revenues - related party (Note 15)		—		37.1
Total revenues	Total revenues	1,448.0		929.6		3,031.8		1,962.3		Total revenues		1,263.1		1,583.8

Costs of product/services sold (exclusive of items shown separately below):	Costs of product/services sold (exclusive of items shown separately below):									Costs of product/services sold (exclusive of items shown separately below):
Product costs	Product costs	1,094.0		768.0		2,384.8		1,535.6		Product costs		991.0		1,290.8
Product costs - related party (Note 15)	Product costs - related party (Note 15)	113.1		25.4		181.6		66.5		Product costs - related party (Note 15)		0.4		68.5
Service costs	Service costs	6.1		3.8		11.2		8.9		Service costs		6.0		5.1
Total costs of product/services sold	Total costs of product/services sold	1,213.2		797.2		2,577.6		1,611.0		Total costs of product/services sold		997.4		1,364.4

Operating expenses and other:	Operating expenses and other:									Operating expenses and other:
Operations and maintenance	Operations and maintenance	46.6		25.8		89.0		58.6		Operations and maintenance		56.6		42.4
General and administrative	General and administrative	25.0		19.7		66.7		36.9		General and administrative		30.2		41.7
Depreciation, amortization and accretion	Depreciation, amortization and accretion	83.0		62.2		161.2		125.0		Depreciation, amortization and accretion		81.3		78.2
(Gain) loss on long-lived assets, net		60.5		(0.3)		64.3		1.1
Loss on long-lived assets, net										Loss on long-lived assets, net		0.4		3.8

		215.1		107.4		381.2		221.6				168.5		166.1
Operating income	Operating income	19.7		25.0		73.0		129.7		Operating income		97.2		53.3
Earnings (loss) from unconsolidated affiliates, net		6.0		(27.1)		9.0		(130.8)
Earnings from unconsolidated affiliates, net										Earnings from unconsolidated affiliates, net		1.7		3.0
Interest and debt expense, net	Interest and debt expense, net	(40.1)		(35.1)		(76.2)		(71.1)		Interest and debt expense, net		(55.6)		(36.1)
Loss on modification/extinguishment of debt		—		(1.2)		—		(6.7)
Income (loss) before income taxes		(14.4)		(38.4)		5.8		(78.9)

Income before income taxes										Income before income taxes		43.3		20.2
Provision for income taxes	Provision for income taxes	(0.2)		(0.1)		(0.2)		—		Provision for income taxes		(0.3)		—
Net income (loss)		(14.6)		(38.5)		5.6		(78.9)
Net income										Net income		43.0		20.2
Net income attributable to non-controlling partner	Net income attributable to non-controlling partner	10.3		10.3		20.5		20.4		Net income attributable to non-controlling partner		10.2		10.2
Net loss attributable to Crestwood Midstream Partners LP		$	(24.9)	$	(48.8)	$	(14.9)	$	(99.3)
Net income attributable to Crestwood Midstream Partners LP										Net income attributable to Crestwood Midstream Partners LP		$	32.8	$	10.0

See accompanying notes.

109

Table of Contents

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 charges	11.8
Taxes paid for unit-based compensation vesting	(14.8)

Net income	32.8
Balance at March 31, 2023	$	1,851.2

Total Partners’ Capital

Balance at December 31, 2021

1,232.3

Non-cash contribution from partner (Note 11)

1,075.1

Cash contribution from partner (Note 11)

14.9

Distributions to partners

(238.1)

Unit-based compensation charges

13.0

Taxes paid for unit-based compensation vesting

(14.9)

Other

0.1

Net income

10.0

Balance at March 31, 2022

~~2,092.4~~

~~Distributions to partners~~

~~(81.6)~~

~~Unit-based compensation charges~~

~~8.6~~

~~Taxes paid for unit-based compensation vesting~~

~~(0.7)~~

~~Net loss~~

~~(24.9)~~

~~Balance at June 30, 2022~~

~~1,993.8~~2,092.4

Total Partners’
Capital

~~Balance at December 31, 2020~~

~~1,805.1~~

~~Distributions to partners~~

~~(334.0)~~

~~Unit-based compensation charges~~

~~2.3~~

~~Taxes paid for unit-based compensation vesting~~

~~(8.1)~~

~~Other~~

~~(0.1)~~

~~Net loss~~

~~(50.5)~~

~~Balance at March 31, 2021~~

~~1,414.7~~

~~Distributions to partners~~

~~(61.4)~~

~~Unit-based compensation charges~~

~~7.6~~

~~Taxes paid for unit-based compensation vesting~~

~~(0.1)~~

~~Net loss~~

~~(48.8)~~

~~Balance at June 30, 2021~~

~~1,312.0~~

See accompanying notes.

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Table of Contents

CRESTWOOD MIDSTREAM PARTNERS LP

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)

(unaudited)

Six Months Ended
June 30,
2022 2021
Operating activities
Net income (loss) $ 5.6 $ (78.9)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion 161.2 125.0
Amortization of debt-related deferred costs and fair value adjustment 1.2 3.4
Unit-based compensation charges 17.2 9.9
Loss on long-lived assets, net 64.3 1.1
Loss on modification/extinguishment of debt — 6.7
(Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received (0.2) 141.1
Deferred income taxes 0.1 —
Other (0.1) 0.1
Changes in operating assets and liabilities 5.9 88.8
Net cash provided by operating activities 255.2 297.2
Investing activities
Purchases of property, plant and equipment (77.5) (21.3)
Investments in unconsolidated affiliates (15.0) (10.2)
Capital distributions from unconsolidated affiliates 6.2 32.9
Net proceeds from sale of assets 25.7 0.5
Net cash provided by (used in) investing activities (60.6) 1.9
Financing activities
Proceeds from the issuance of long-term debt 1,649.8 2,005.6
Payments on long-term debt (1,470.8) (1,866.8)
Payments on finance leases (30.4) (1.4)
Payments for deferred financing costs (1.7) (11.1)
Contribution from partner 14.9 —
Distributions to partners (319.7) (395.4)
Distributions to non-controlling partner (20.7) (19.6)
Taxes paid for unit-based compensation vesting (15.6) (8.2)
Net cash used in financing activities (194.2) (296.9)
Net change in cash 0.4 2.2
Cash at beginning of period 12.9 13.7
Cash at end of period $ 13.3 $ 15.9
Supplemental schedule of non-cash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses $ 14.5 $ (29.2)

~~Table of Contents~~

~~CRESTWOOD MIDSTREAM PARTNERS LP~~

~~CONSOLIDATED STATEMENTS OF CASH FLOWS (continued)~~

~~(in millions)~~

~~(unaudited)~~

Six Months Ended
June 30,
2022 2021
Supplemental schedule of non-cash financing activities
Non-cash contribution:
Current assets $ 63.2 $ —
Property, plant and equipment 1,264.4 —
Intangible assets 464.0 —
Goodwill 56.2 —
Current liabilities (48.2) —
Debt (698.7) —
Other liabilities (25.8) —
Total non-cash contribution $ 1,075.1 $ —


	Three Months Ended
	March 31,
	2023		2022
Operating activities
Net income	$	43.0	$	20.2
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	81.3		78.2
Amortization of debt-related deferred costs and fair value adjustment	0.8		0.8
Unit-based compensation charges	10.0		8.6
Loss on long-lived assets, net	0.4		3.8



Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	(1.4)		(0.4)
Deferred income taxes	0.1		—
Other	—		(0.1)
Changes in operating assets and liabilities	113.8		112.8
Net cash provided by operating activities	248.0		223.9
Investing activities

Purchases of property, plant and equipment	(67.3)		(26.4)
Investments in unconsolidated affiliates	(5.1)		(14.5)
Capital distributions from unconsolidated affiliates	1.7		5.9
Net proceeds from sale of assets	0.3		0.4

Net cash used in investing activities	(70.4)		(34.6)
Financing activities
Proceeds from the issuance of long-term debt	1,153.7		919.1
Payments on long-term debt	(1,209.2)		(859.1)
Payments on finance leases	(0.8)		(0.8)
Payments for deferred financing costs	(9.1)		(1.7)

Contributions from partner	—		14.9
Distributions to partners	(85.9)		(238.1)
Distributions to non-controlling partner	(10.3)		(10.3)
Taxes paid for unit-based compensation vesting	(14.8)		(14.9)

Net cash used in financing activities	(176.4)		(190.9)
Net change in cash	1.2		(1.6)
Cash at beginning of period	7.1		12.9
Cash at end of period	$	8.3	$	11.3
Supplemental schedule of non-cash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$	(16.8)	$	3.8

See accompanying notes.

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CRESTWOOD EQUITY PARTNERS LP

CRESTWOOD MIDSTREAM PARTNERS LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 1 – Organization and Business Description

The accompanying notes to the consolidated financial statements apply to Crestwood Equity Partners LP (Crestwood Equity or CEQP) and Crestwood Midstream Partners LP (Crestwood Midstream or CMLP), unless otherwise indicated.

The accompanying consolidated financial statements and related notes should be read in conjunction with our ~~2021~~2022 Annual Report on Form 10-K filed with the Securities and Exchange Commission (SEC) on February ~~25, 2022.~~27, 2023. The financial information as of ~~June 30, 2022~~March 31, 2023 and for the three ~~and six~~ months ended ~~June 30,~~March 31, 2023 and 2022, ~~and 2021,~~ is unaudited. The consolidated balance sheets as of December 31, ~~2021~~2022 were derived from the audited balance sheets filed in our ~~2021~~2022 Annual Report on Form 10-K.

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

Organization

Crestwood Equity Partners LP. CEQP is a publicly-traded (NYSE: CEQP) Delaware limited partnership formed in March 2001. Crestwood Equity GP LLC, ~~(Crestwood Equity GP),~~ our wholly-owned subsidiary, owns our non-economic general partnership interest.

Crestwood Midstream Partners LP. Crestwood Equity owns a 99.9% limited partnership interest in Crestwood Midstream and Crestwood Gas Services GP LLC, ~~(CGS GP),~~ a wholly-owned subsidiary of Crestwood Equity, owns a 0.1% limited partnership interest in Crestwood Midstream. Crestwood Midstream GP LLC, a wholly-owned subsidiary of Crestwood Equity, owns the non-economic general partnership interest of Crestwood Midstream.

Business Description

Crestwood Equity develops, acquires, owns or controls, and operates primarily fee-based assets and operations within the energy midstream sector. We provide broad-ranging infrastructure solutions across the value chain to service premier liquids-rich natural gas and crude oil shale plays across ~~the United States.~~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 ~~(GAAP)~~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.

1412

Table of Contents

Significant Accounting Policies

There were no material changes in our significant accounting policies from those described in our ~~2021~~2022 Annual Report on Form 10-K.

Note 3 – Acquisition ~~and Divestitures~~

~~Acquisition~~

On October 25, 2021, we entered into a merger agreement to acquire Oasis Midstream Partners LP (Oasis Midstream) in an equity and cash transaction (the Merger). Oasis Midstream is a master limited partnership which operates a diversified portfolio of midstream assets located in the Williston and Delaware Basins and its operations include natural gas services (gathering, compression, processing and gas lift supply), crude oil services (gathering, terminalling and transportation), and water services (gathering and disposal of produced and flowback water and freshwater distribution).

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

We accounted for the Merger as a business combination using the acquisition method of accounting. In addition, the purchase accounting reflects the adoption of Accounting Standards Update (ASU) 2021-08, ~~Business Combinations (Topic 805)~~ during the six months ended June 30, 2022. The financial results of Oasis Midstream’s Williston Basin operations are included in our gathering and processing north segment and Oasis Midstream’s Delaware Basin operations are included in our gathering and processing south segment from the date of acquisition. During the six months ended June 30, 2022, we recognized approximately $18.7 million of transaction costs related to the Merger, which are included in general and administrative expenses in our consolidated statements of operations.

The fair value of the assets acquired and liabilities assumed were determined primarily utilizing market related information and other projections on the performance of the assets acquired, including an analysis of discounted cash flows at a discount rate of approximately 12%. Certain fair values are Level 3 fair value measurements and were developed by management with the assistance of a third-party valuation firm. We estimated the fair value of the senior notes assumed based on quoted market prices for similar issuances which are considered Level 2 fair value measurements.

~~Table of Contents~~

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


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

(1) Consists of approximately $218 million outstanding borrowings under the Oasis Midstream credit facility, which was immediately repaid upon the closing of the Merger and approximately $450 million of unsecured senior notes and the related fair value adjustment of approximately $30.7 million. For a further discussion of the long-term debt assumed in conjunction with the Merger, see Note 8.

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

The identifiable intangible assets primarily consist of customer accounts with Oasis Petroleum and other customers with a weighted-average remaining life of 20 years. The goodwill recognized relates primarily to the anticipated operating synergies between the assets acquired and our existing operations. We reflected approximately $48.8 million of goodwill in our gathering and processing north segment and approximately $7.4 million in our gathering and processing south segment.

Our consolidated statements of operations include the results of Oasis Midstream since February 1, 2022, the closing date of the Merger. During the three and six months ended June 30, 2022, we recognized approximately $97.5 million and $164.3 million of revenues and $32.8 million and $56.3 million of net income related to Oasis Midstream’s operations.

~~The tables below present selected unaudited pro forma information as if the Merger had occurred on January 1, 2021 (in millions~~). The pro forma information is not necessarily indicative of the financial results that would have occurred if the Merger had been completed as of the date indicated. The amounts were calculated after applying our accounting policies and adjusting the results to reflect the depreciation, amortization and accretion expense that would have been charged assuming the fair value adjustments to property, plant and equipment and intangible assets had been made at the beginning of the reporting period. The pro forma net income (loss) also includes the net effects of interest expense on incremental borrowings, repayments of long-term debt and amortization of the fair value adjustment to long-term debt.

~~Crestwood Equity~~

Three Months Ended June 30, Six Months Ended June 30,
2021 2022 2021
Revenues $ 1,024.9 $ 3,066.4 $ 2,157.9
Net income (loss) $ (15.5) $ 67.8 $ (31.1)
Net income (loss) per limited partner unit:
Basic $ (0.42) $ 0.18 $ (0.80)
Diluted $ (0.42) $ 0.17 $ (0.80)

~~Table of Contents~~

~~Crestwood Midstream~~

Three Months Ended June 30, Six Months Ended June 30,
2021 2022 2021
Revenues $ 1,024.9 $ 3,066.4 $ 2,157.9
Net income (loss) $ (15.9) $ 11.8 $ (33.6)

~~Divestitures~~

On July 1, 2022, we sold our assets in the Barnett Shale to EnLink Midstream, LLC for approximately $290 million, including working capital adjustments. As a result of the sale, we reflected these assets as current assets held for sale, net, on our consolidated balance sheets at June 30, 2022. Crestwood Midstream recorded a loss on long-lived assets of approximately $53.3 million during the three months ended June 30, 2022 for the difference between the historical carrying value of the net assets and liabilities to be sold and the proceeds received from the sale. Crestwood Equity’s historical carrying value of the property, plant and equipment related to our Barnett Shale assets was less than the anticipated sales proceeds due to historical impairments previously recorded on the property, plant and equipment by Crestwood Equity and as a result, Crestwood Equity did not record a gain or loss on long-lived assets during the three and six months ended June 30, 2022 related to the reclassification of these net assets as current assets held for sale. The current assets held for sale at Crestwood Midstream were recorded at fair value based on the sales proceeds, which is a Level 3 fair value measurement. For a further description of our assets in the Barnett Shale, which are included in our gathering and processing south segment, see our 2021 Annual Report on Form 10-K. During the three months ended June 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):


		June 30,		December 31,			March 31,		December 31,
		2022		2021			2023		2022
CMLP	CMLP					CMLP
Accrued expenses	Accrued expenses	$	49.2	$	66.3	Accrued expenses	$	49.2	$	66.5
Accrued property taxes	Accrued property taxes	5.2		4.4		Accrued property taxes	6.0		8.4
Income tax payable	Income tax payable	0.1		0.4		Income tax payable	1.0		0.9
Interest payable	Interest payable	40.8		30.6		Interest payable	65.6		43.2
Accrued additions to property, plant and equipment	Accrued additions to property, plant and equipment	38.0		17.4		Accrued additions to property, plant and equipment	18.9		35.6
Operating leases	Operating leases	9.5		13.2		Operating leases	10.5		10.9
Finance leases	Finance leases	2.2		1.7		Finance leases	1.7		1.9
Contract liabilities	Contract liabilities	11.9		10.7		Contract liabilities	13.8		11.7
Asset retirement obligations	Asset retirement obligations	0.4		1.4		Asset retirement obligations	0.3		0.4
Total CMLP accrued expenses and other liabilities	Total CMLP accrued expenses and other liabilities	$	157.3	$	146.1	Total CMLP accrued expenses and other liabilities	$	167.0	$	179.5
CEQP	CEQP					CEQP
Accrued expenses	Accrued expenses	1.2		0.9		Accrued expenses	0.9		1.2
Income tax payable	Income tax payable	0.1		0.1		Income tax payable	—		0.1
Total CEQP accrued expenses and other liabilities	Total CEQP accrued expenses and other liabilities	$	158.6	$	147.1	Total CEQP accrued expenses and other liabilities	$	167.9	$	180.8

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Other Long-Term Liabilities

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


		June 30,		December 31,			March 31,		December 31,
		2022		2021			2023		2022
CMLP	CMLP					CMLP
Contract liabilities	Contract liabilities	$	203.7	$	187.1	Contract liabilities	$	205.9	$	212.3
Intangible liabilities, net						Intangible liabilities, net	48.5		50.0
Asset retirement obligations						Asset retirement obligations	37.3		36.4
Operating leases	Operating leases	13.8		19.4		Operating leases	17.5		17.4
Asset retirement obligations		35.0		34.8
Other	Other	13.7		12.8		Other	14.3		14.2
Total CMLP other long-term liabilities	Total CMLP other long-term liabilities	$	266.2	$	254.1	Total CMLP other long-term liabilities	$	323.5	$	330.3
CEQP	CEQP					CEQP
Other	Other	1.8		4.6		Other	1.5		3.1
Total CEQP other long-term liabilities	Total CEQP other long-term liabilities	$	268.0	$	258.7	Total CEQP other long-term liabilities	$	325.0	$	333.4

Note 5 - Investments in Unconsolidated Affiliates

Net Investments and Earnings (Loss) of Unconsolidated Affiliates

Our net investments in and earnings (loss) from our unconsolidated affiliates are as follows (in millions):


		Investment				Earnings (Loss) from Unconsolidated Affiliates				Earnings (Loss) from Unconsolidated Affiliates					Investment				Earnings (Loss) from Unconsolidated Affiliates
						Three Months Ended				Six Months Ended									Three Months Ended
		June 30,		December 31,		June 30,				June 30,					March 31,		December 31,		March 31,
		2022		2021		2022		2021		2022		2021			2023		2022			2023		2022
Crestwood Permian Basin Holdings LLC(1)		$	118.4	$	116.1	$	4.8	$	1.0	$	7.4	$	0.2
Crestwood Permian Basin LLC(1)														Crestwood Permian Basin LLC(1)	$	74.8	$	76.5		$	0.3	$	—
Tres Palacios Holdings LLC(2)	Tres Palacios Holdings LLC(2)	43.2		36.2		1.3		(0.1)		1.9		9.2		Tres Palacios Holdings LLC(2)	46.5		39.8			1.6		0.6
Powder River Basin Industrial Complex, LLC(3)	Powder River Basin Industrial Complex, LLC(3)	3.2		3.5		(0.1)		—		(0.3)		0.1		Powder River Basin Industrial Complex, LLC(3)	3.0		3.2			(0.2)		(0.2)
Stagecoach Gas Services LLC(4)		—		—		—		(28.0)		—		(140.3)
Crestwood Permian Basin Holdings LLC(4)														Crestwood Permian Basin Holdings LLC(4)	—		—			—		2.6
Total	Total	$	164.8	$	155.8	$	6.0	$	(27.1)	$	9.0	$	(130.8)	Total	$	124.3	$	119.5		$	1.7	$	3.0

(1)In July 2022, we acquired the remaining 50% equity interest in Crestwood Permian Basin Holdings LLC (Crestwood Permian), whose operations included its 50% equity interest in Crestwood Permian Basin LLC (Crestwood Permian Basin). As of ~~June 30, 2022,~~March 31, 2023, our equity in the underlying net assets of Crestwood Permian Basin ~~Holdings LLC (Crestwood Permian) exceeded~~was less than the carrying value of our investment balance by ~~$8.2~~approximately $2.3 million. During the three months ended March 31, 2023, we recorded amortization of less than $0.1 million ~~and~~related to this ~~excess amount~~basis difference, which is ~~not subject to amortization.~~reflected as a decrease in our earnings from unconsolidated affiliates in our consolidated statement of operations. Our Crestwood Permian Basin investment is included in our gathering and processing south segment. ~~On July 11, 2022, we acquired the remaining 50% equity interest in Crestwood Permian. See Note 16 for a further discussion of this acquisition.~~

(2)As of ~~June 30, 2022,~~March 31, 2023, our equity in the underlying net assets of Tres Palacios Holdings LLC (Tres Holdings) exceeded the carrying value of our investment balance by approximately ~~$20.9~~$19.9 million. During both the three ~~and six~~ months ended ~~June 30,~~March 31, 2023 and 2022, ~~and 2021,~~ we recorded amortization of approximately $0.3 million ~~and $0.6 million, respectively,~~ related to this excess basis, which is reflected as an increase in our earnings from unconsolidated affiliates in our consolidated statements of operations. Our Tres Holdings investment is included in our storage and logistics segment.

(3)As of ~~June 30, 2022,~~March 31, 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 2021,~~As discussed above, in July 2022, we ~~and Con Edison Gas Pipeline and Storage Northeast, LLC each sold our~~acquired the remaining 50% equity interest in ~~our Stagecoach Gas Services LLC (Stagecoach Gas) equity investment to~~Crestwood Permian and as a ~~subsidiary~~result, we control and own 100% of Kinder Morgan, Inc. During the three and six months ended June 30, 2021, we recorded a $35.5 million and $155.4 million reduction in our equity earnings from unconsolidated affiliates related to losses recorded by us and our Stagecoach Gas equity investment associated with the sale, which also eliminated our $51.3 million historical basis difference between our investment balance and the equity interests in the underlying net assets of Stagecoach Gas. In addition, our earnings from unconsolidated affiliates during the three and six months ended June 30, 2021, were also reduced by our proportionate share of transaction costs of approximately $3.0 million related to the sale, which were paid by us in July 2021 on behalf of Stagecoach Gas.Crestwood Permian. Our ~~Stagecoach Gas~~Crestwood Permian investment was previously included in our ~~storage~~gathering and ~~logistics~~processing south segment.

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 Holdings for total consideration of approximately $335.0 million, plus working capital adjustments. The sale was completed on April 3, 2023 and we received net proceeds of approximately $178.3 million.

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Distributions and Contributions

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

Distributions(1)
Contributions
Six Months Ended Six Months Ended
June 30, June 30,
2022 2021 2022 2021
Crestwood Permian $ 13.6 $ 5.5 $ 8.5 $ 3.3
Tres Holdings 1.4 10.6 6.5 6.9
PRBIC — 0.1 — —
Stagecoach Gas — 27.0 — —
Total $ 15.0 $ 43.2 $ 15.0 $ 10.2

(1) In July 2022, we received cash distributions from Crestwood Permian and Tres Holdings of approximately $5.9 million and $3.4 million, respectively. In July 2022, we made a cash contribution of $75.0 million to Crestwood Permian prior to the acquisition of the remaining 50% equity interest in Crestwood Permian, which is further discussed in Note 16. In July 2022, we made a cash contribution of $0.3 million to Tres Holdings.


	Distributions				Contributions
	Three Months Ended				Three Months Ended
	March 31,				March 31,
	2023		2022		2023		2022
Crestwood Permian Basin	$	2.0	$	—	$	—	$	—
Tres Holdings	—		—		5.1		6.0

Crestwood Permian	—		8.5		—		8.5
Total	$	2.0	$	8.5	$	5.1	$	14.5

Note 6 – Risk Management

We are exposed to certain market risks related to our ongoing business operations. These risks include exposure to changing commodity prices. We utilize derivative instruments to manage our exposure to fluctuations in commodity prices, which is discussed below. Additional information related to our derivatives is discussed in Note 7.

Risk Management Activities

We sell NGLs (such as propane, ethane, butane and heating oil), crude oil and natural gas to energy-related businesses and may use a variety of financial and other instruments including forward contracts involving physical delivery of NGLs, crude oil and natural gas. We periodically enter into offsetting positions to economically hedge against the exposure our customer contracts create. Certain of these contracts and positions are derivative instruments. We do not designate any of our commodity-based derivatives as hedging instruments for accounting purposes. Our commodity-based derivatives are reflected at fair value in our consolidated balance sheets, and changes in the fair value of these derivatives that impact the consolidated statements of operations are reflected in costs of product/services sold. Our commodity-based derivatives that are settled with physical commodities are reflected as an increase to product revenues, and the commodity inventory that is utilized to satisfy those physical obligations is reflected as an increase to product costs in our consolidated statements of operations. 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 ~~impact to~~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				Six Months Ended					Three Months Ended
		June 30,				June 30,					March 31,
		2022		2021		2022		2021				2023		2022
Product revenues	Product revenues	$	108.8	$	52.7	$	311.0	$	167.5	Product revenues		$	145.8	$	202.2
Loss reflected in product costs		$	(3.7)	$	(33.3)	$	(51.3)	$	(41.4)
Product costs, net										Product costs, net		$	(7.2)	$	47.6

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.

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Notional Amounts and Terms

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


		June 30, 2022		December 31, 2021			March 31, 2023		December 31, 2022
		Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver		Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, ethane, butane, heating oil and crude oil (MMBbls)	Propane, ethane, butane, heating oil and crude oil (MMBbls)	60.3	62.8	71.6	75.8	Propane, ethane, butane, heating oil and crude oil (MMBbls)	63.4	65.5	67.2	70.2
Natural gas (Bcf)	Natural gas (Bcf)	42.4	48.6	31.9	43.4	Natural gas (Bcf)	15.5	15.8	44.2	48.4

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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 3736 months or less; however, ~~87%~~92% of the contracted volumes will be delivered or settled within 12 months.

Credit Risk

Inherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. The counterparties associated with our price risk management activities are energy marketers and propane retailers, resellers and dealers.

Certain of our derivative instruments have credit limits that require us to post collateral. The amount of collateral required to be posted is a function of the net liability position of the derivative as well as our established credit limit with the respective counterparty. If our credit rating were to change, the counterparties could require us to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent of change in our credit rating as well as the requirements of the individual counterparty. ~~In addition, we have margin requirements with a derivative clearing broker and a third party broker related to our net asset or liability position with each respective broker.~~ All collateral amounts have been netted against the asset or liability with the respective counterparty and are reflected in our consolidated balance sheets as assets and liabilities from price risk management activities.

~~The following table presents~~ For a summary of the fair value of our commodity derivative instruments with credit-risk related contingent features and their associated collateral, (~~in millions~~):

June 30, 2022 December 31, 2021
Aggregate fair value liability of derivative instruments with credit-risk-related contingent features(1)
$ 53.9 $ 57.9
Broker-related net derivative asset position $ 67.4 $ 104.8
Broker-related cash collateral received $ 45.6 $ 76.8
Cash collateral (paid) received, net $ (2.8) $ 11.4
see Note 7.

~~(1)At June 30, 2022 and December 31, 2021, we posted $11.7 million and $1.5 million of collateral associated with these derivatives.~~

Note 7 – Fair Value Measurements

The accounting standard for fair value measurement establishes a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows:

•Level ~~1—Quoted prices~~1 — Includes inputs that are ~~available~~observable in active markets for identical assets or liabilities as of the reporting ~~date. Active markets are those in which transactions for Level 1 primarily consists of financial instruments~~date such as exchange-traded derivatives, listed equities and US government treasury securities.

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•Level ~~2—Pricing~~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. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives such as over the counter (OTC) forwards, options and physical exchanges.

•Level ~~3—Pricing inputs include~~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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~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 are not traded on a public exchange. The fair values of these derivative instruments are determined based on inputs that are readily available in public markets or can be derived from information available in publicly quoted markets. These instruments have been categorized as Level 2.

Our OTC options are valued based on the Black Scholes option pricing model that considers time value and volatility of the underlying commodity. The inputs utilized in the model are based on publicly available information as well as broker quotes. These options have been categorized as Level 2.

Our financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

~~The following tables set forth by level within the fair value hierarchy, our financial instruments that were accounted for at fair value on a recurring basis at June 30, 2022 and December 31, 2021 (in millions~~):

June 30, 2022
Level 1 Level 2 Level 3 Gross Fair Value
Contract Netting(1)
Collateral/Margin Received or Paid Fair Value
Assets
Assets from price risk management $ 42.5 $ 512.2 $ — $ 554.7 $ (474.5) $ (46.0) $ 34.2
Other investments(2)
2.3 — — 2.3 — — 2.3
Total assets at fair value $ 44.8 $ 512.2 $ — $ 557.0 $ (474.5) $ (46.0) $ 36.5
Liabilities
Liabilities from price risk management $ 55.6 $ 504.4 $ — $ 560.0 $ (474.5) $ (3.2) $ 82.3
Total liabilities at fair value $ 55.6 $ 504.4 $ — $ 560.0 $ (474.5) $ (3.2) $ 82.3

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December 31, 2021
Level 1 Level 2 Level 3 Gross Fair Value
Contract Netting(1)
Collateral/Margin Received or Paid Fair Value
Assets
Assets from price risk management $ 33.3 $ 695.6 $ — $ 728.9 $ (607.4) $ (79.4) $ 42.1
Other investments(2)
2.2 — — 2.2 — — 2.2
Total assets at fair value $ 35.5 $ 695.6 $ — $ 731.1 $ (607.4) $ (79.4) $ 44.3
Liabilities
Liabilities from price risk management $ 26.9 $ 686.3 $ — $ 713.2 $ (607.4) $ 8.8 $ 114.6
Total liabilities at fair value $ 26.9 $ 686.3 $ — $ 713.2 $ (607.4) $ 8.8 $ 114.6
The following tables summarize the fair value hierarchy of our financial instruments that were reflected in our consolidated balance sheets (in millions):


	March 31, 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	$	17.4	$	231.3	$	—	$	248.7	$	(219.6)	$	2.3	$	31.4
Other investments(2)	2.6		—		—		2.6		—		—		2.6
Total assets at fair value	$	20.0	$	231.3	$	—	$	251.3	$	(219.6)	$	2.3	$	34.0

Liabilities
Liabilities from price risk management with credit-risk-related contingent features	$	13.6	$	208.3	$	—	$	221.9	$	(219.6)	$	7.1	$	9.4
Liabilities from price risk management without credit-risk-related contingent features	—		2.7		—		2.7		—		1.1		3.8
Total liabilities at fair value	$	13.6	$	211.0	$	—	$	224.6	$	(219.6)	$	8.2	$	13.2

	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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~2022, the carrying amounts of cash, accounts receivable and accounts payable approximate fair value based on the short-term nature of these instruments.

Credit ~~Facility~~Facilities

The fair value of the amounts outstanding under our ~~Crestwood Midstream~~ credit ~~facility~~facilities approximates ~~the~~their respective carrying amounts as of ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~2022, primarily due ~~primarily~~ to the variable nature of the interest ~~rate~~rates of the ~~instrument,~~instruments, which is considered a Level 2 fair value measurement. See Note 8 for a further discussion of our credit facilities.

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Senior Notes

We estimate the fair value of our senior notes primarily based on quoted market prices for the same or similar issuances (representing a Level 2 fair value measurement). The following table represents the carrying amount (reduced for deferred financing costs associated with the respective notes) and fair value of our senior notes (in millions):


		June 30, 2022				December 31, 2021					March 31, 2023				December 31, 2022
		Carrying Amount		Fair Value		Carrying Amount		Fair Value			Carrying Amount		Fair Value		Carrying Amount		Fair Value
2025 Senior Notes	2025 Senior Notes	$	497.1	$	471.1	$	496.5	$	511.9	2025 Senior Notes	$	497.9	$	490.5	$	497.6	$	486.7
2027 Senior Notes	2027 Senior Notes	$	594.8	$	537.0	$	594.2	$	615.0	2027 Senior Notes	$	595.6	$	576.5	$	595.3	$	556.9
February 2029 Senior Notes	February 2029 Senior Notes	$	691.5	$	614.5	$	690.8	$	727.3	February 2029 Senior Notes	$	692.5	$	669.0	$	692.1	$	642.1
April 2029 Senior Notes(1)	April 2029 Senior Notes(1)	$	478.9	$	420.3	$	—	$	—	April 2029 Senior Notes(1)	$	475.7	$	461.5	$	476.7	$	450.0
2031 Senior Notes										2031 Senior Notes	$	591.1	$	604.1	$	—	$	—

(1)~~Represents $450 million of unsecured senior notes assumed~~ The carrying amount includes a fair value adjustment we recorded in conjunction with the merger with Oasis Midstream discussed in Note ~~3, and the related net~~3. For a further discussion of this fair value adjustment, ~~which is further described in~~see Note 8.

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Note 8 – Long-Term Debt

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

June 30,
2022 December 31,
2021
Credit Facility $ 679.0 $ 282.0
2025 Senior Notes 500.0 500.0
2027 Senior Notes 600.0 600.0
February 2029 Senior Notes 700.0 700.0
April 2029 Senior Notes 450.0 —
April 2029 Senior Notes fair value adjustment, net 28.9 —
Other(1)
0.2 0.2
Less: deferred financing costs, net 28.6 29.9
Total debt 2,929.5 2,052.3
Less: current portion 0.2 0.2
Total long-term debt, less current portion $ 2,929.3 $ 2,052.1


	March 31, 2023		December 31, 2022
CMLP Credit Facility	$	473.6	$	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)	25.7		26.7
2031 Senior Notes	600.0		—

Less: deferred financing costs, net	34.8		27.5


Total long-term debt	$	3,314.5	$	3,378.3

(1)~~Represents non-interest bearing obligations~~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. During the three months ended March 31, 2023 and 2022, we recorded a reduction to our interest and debt expense of approximately $1.0 million and $0.7 million related to ~~certain companies acquired in 2014 with payments due through 2022.~~the amortization of the fair value adjustment.

Credit ~~Facility~~Facilities

CMLP Credit Facility.Crestwood Midstream’s five-year ~~$1.5~~$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 Tres Holdings 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.

Under the credit agreement, Crestwood Midstream is required ~~under its credit agreement~~ to maintain a net debt to consolidated EBITDA ratio (as defined in ~~its~~the credit agreement) of not more than 5.50 to 1.0, a consolidated EBITDA to consolidated interest expense ratio (as defined in ~~its~~the credit agreement) of not less than 2.50 to 1.0, and a senior secured leverage ratio (as defined in ~~its~~the credit agreement) of

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not more than 3.50 to 1.0. At ~~June 30, 2022,~~March 31, 2023, the net debt to consolidated EBITDA ratio was approximately ~~3.69~~4.18 to 1.0, the consolidated EBITDA to consolidated interest expense ratio was approximately ~~5.02~~4.25 to 1.0, and the senior secured leverage ratio was ~~0.86~~0.59 to 1.0.

At ~~June 30, 2022,~~March 31, 2023, Crestwood Midstream had ~~$812.2 million~~$1.1 billion of available capacity under ~~its credit facility~~the CMLP Credit Facility considering the most restrictive debt covenants in ~~its~~the credit agreement. At ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021, Crestwood Midstream’s~~2022, outstanding standby letters of credit under the CMLP Credit Facility were ~~$8.8~~$7.9 million and ~~$6.3~~$8.2 million. Borrowings under the ~~credit facility~~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 ~~2.98%~~6.76% and ~~5.50%~~9.00% at ~~June 30, 2022~~March 31, 2023 and ~~1.90%~~6.28% and ~~4.00%~~8.50% at December 31, ~~2021.~~2022. The weighted-average interest rate on outstanding borrowings as of ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021~~2022 was ~~3.64%~~6.96% and ~~1.91%~~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 (CPB Holdings), 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 Notes

~~February 2029~~2031 Senior Notes. In January ~~2021,~~2023, Crestwood Midstream issued ~~$700~~$600 million of ~~6.00%~~7.375% unsecured senior notes due ~~2029~~2031 (the ~~February 2029~~2031 Senior Notes). The ~~February 2029~~2031 Senior Notes will mature on February 1, ~~2029,~~2031, and interest is payable semi-annually in arrears on February 1 and August 1 of each year, beginning on August 1, ~~2021.~~2023. The net proceeds from this offering of approximately ~~$691.0~~$592.5 million were used to repay ~~a portion of our senior notes that were due in 2023 and to repay indebtedness~~borrowings outstanding under the CMLP Credit Facility.

~~April 2029 Senior Notes.~~In February 2022, in conjunction with the merger with Oasis Midstream, we assumed $450 million of 8.00% unsecured senior notes due 2029 (the April 2029 Senior Notes) and we recorded a fair value adjustment of approximately $30.7 million related to the senior notes. During the three and six months ended June 30, 2022, we recorded a reduction to our interest and debt expense of approximately $1.1 million and $1.8 million related to the amortization of the fair value adjustment. The April 2029 Senior Notes will mature on April 1, 2029, and interest is payable semi-annually on April 1 and October 1 of each year.

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~~2023 Senior Note Repayments~~. During the six months ended June 30, 2021, we redeemed $687.2 million of principal outstanding under our senior notes due in 2023. In conjunction with the repayment of the notes, we recognized a loss on extinguishment of debt of approximately $1.2 million and $6.7 million during the three and six months ended June 30, 2021, and paid approximately $8.6 million of accrued interest on our senior notes due in 2023 on the dates they were repurchased. During 2021, we repaid all amounts outstanding under our senior notes due 2023 and funded the repayment using a portion of the proceeds from the issuance of the February 2029 Senior Notes and borrowings under the CMLP credit facility.

Note 9 – Commitments and Contingencies

Legal Proceedings

Linde Lawsuit. On December 23, 2019, Linde Engineering North America Inc. (Linde) filed a lawsuit in the District Court of Harris County, Texas alleging that Arrow Field Services, LLC, our consolidated subsidiary, and Crestwood Midstream breached a contract entered into in March 2018 under which Linde was to provide engineering, procurement and construction services to us related to the completion of the construction of the Bear Den II cryogenic processing plant. Since the lawsuit was filed, we have paid Linde approximately $22.7 million related to this matter (including approximately $3.2 million paid during the six months ended June 30, 2022). Linde claims remaining unpaid invoices of approximately $33 million, along with other damages.

A jury trial ~~related to this lawsuit~~ concluded on June 17, 2022, ~~at which the jury awarded Linde damages which we estimate to be approximately $29.7 million, including~~and a ~~potential pre-judgment interest award. A~~final judgement was entered on October 24, 2022. The final judgment ~~has not been rendered in the trial,~~includes an award of damages of approximately $20.7 million, a pre-judgement interest award of approximately $17.7 million and ~~we are evaluating our potential legal options related to the potential judgment.~~attorney fees and other costs of approximately $4.7 million. We have insurance coverage related to certain ~~litigation-related~~pre-judgement interest awards but have not recorded a receivable related to any potential insurance recovery at ~~June 30, 2022.~~March 31, 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 we are unable to predict the ~~final~~ultimate outcome ~~for~~on 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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~2022, we had approximately ~~$30.0~~$9.0 million and ~~$16.8~~$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.

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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.

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At ~~June 30, 2022~~both March 31, 2023 and December 31, ~~2021,~~2022, our accrual ~~of approximately $0.9~~for environmental matters was less than $1.0 million and our potential exposure related to environmental matters was less than $1.0 million was based on our undiscounted estimate of amounts we will spend on compliance with environmental and other regulations, and any associated fines or penalties. We estimate that our potential liability for reasonably possible outcomes related to our environmental exposures could range from approximately $0.9 million to $1.7 million at ~~June 30, 2022.~~March 31, 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
June 30,
2022 December 31, 2021 June 30,
2022 December 31, 2021
Self-insurance reserves(1)
$ 5.3 $ 5.5 $ 4.3 $ 4.7


	CEQP				CMLP
	March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022
Self-insurance reserves(1)	$	5.5	$	5.6	$	4.7	$	4.8

(1)At ~~June 30, 2022,~~March 31, 2023, CEQP and CMLP classified approximately ~~$3.5~~$3.2 million and ~~$2.9~~$2.7 million, respectively, of these reserves as other long-term liabilities on their consolidated balance sheets.

~~Guarantees and~~ Indemnifications

We periodically provide indemnification arrangements related to assets or businesses we have sold. Our potential exposure under indemnification arrangements can range from a specified amount to an unlimited amount, depending on the nature of the claim, specificity as to duration, and the particular transaction. As of ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~2022, we have no amounts accrued for these indemnifications.

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Note 10 - Leases

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

June 30,
2022 December 31, 2021
Operating Leases
Operating lease right-of-use assets, net $ 18.8 $ 27.4
Accrued expenses and other liabilities $ 9.5 $ 13.2
Other long-term liabilities 13.8 19.4
Total operating lease liabilities $ 23.3 $ 32.6
Finance Leases
Property, plant and equipment $ 15.1 $ 12.3
Less: accumulated depreciation 10.9 9.2
Property, plant and equipment, net $ 4.2 $ 3.1
Accrued expenses and other liabilities $ 2.2 $ 1.7
Other long-term liabilities 1.9 1.2
Total finance lease liabilities $ 4.1 $ 2.9

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	March 31, 2023		December 31, 2022
Operating Leases
Operating lease right-of-use assets, net	$	24.4	$	24.4

Accrued expenses and other liabilities	$	10.5	$	10.9
Other long-term liabilities	17.5		17.4
Total operating lease liabilities	$	28.0	$	28.3
Finance Leases
Property, plant and equipment	$	13.5	$	13.6
Less: accumulated depreciation	8.9		8.9
Property, plant and equipment, net	$	4.6	$	4.7

Accrued expenses and other liabilities	$	1.7	$	1.9
Other long-term liabilities	2.7		2.7
Total finance lease liabilities	$	4.4	$	4.6

Lease expense. Our operating lease expense, net totaled ~~$2.3~~$3.8 million and ~~$4.3~~$3.5 million for the three months ended ~~June 30, 2022~~March 31, 2023 and ~~2021 and $5.8 million and $9.1 million for the six months ended June 30, 2022 and 2021.~~2022. Our finance lease expense totaled $0.8 million and $0.9 million for ~~both~~ the three months ended ~~June 30, 2022~~March 31, 2023 and ~~2021 and $1.8 million for both the six months ended June 30, 2022 and 2021.~~2022.

Other. ~~During~~In March 2022, we exercised an option to purchase crude oil railcars under certain of our ~~operating~~finance leases as a result of our plan to exit our crude oil railcar operations. ~~In April~~During the three months ended March 31, 2022, ~~we sold the crude oil railcars to a third party for approximately $24.7 million and~~ we recognized a loss on ~~the~~long-lived assets of approximately $4.0 million related to our anticipated sale of ~~approximately $0.1 million and $4.1 million during the three and six months ended June 30, 2022.~~these crude oil railcars.

Note 11 – Partners’ Capital and Non-Controlling Partner

Common ~~and Subordinated~~ Units

On February 1, 2022, we completed the merger with Oasis Midstream. Pursuant to the merger agreement, ~~Oasis Petroleum~~Chord received cash ~~plus~~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.

In March 2021, CEQP acquired approximately 11.5 million CEQP common units and 0.4 million subordinated units of CEQP from Crestwood Holdings LLC (Crestwood Holdings) for approximately $268 million (Crestwood Holdings Transactions). CEQP reflected the purchase price as a reduction to its common unitholders’ partners’ capital in its consolidated statement of partners’ capital during the first quarter of 2021. This transaction resulted in CEQP retiring the common and subordinated units acquired from Crestwood Holdings. In addition, in conjunction with this transaction, CEQP eliminated approximately $2.4 million of accounts payable to Crestwood Holdings which is reflected as an increase to CEQP’s common unitholders’ partners’ capital in its consolidated statements of partners’ capital during the first quarter of 2021. Transaction costs related to this transaction of approximately $7.6 million are reflected as a reduction of CEQP’s common unitholders’ partners’ capital in its consolidated statement of partners’ capital during the first quarter of 2021.

Distributions

Crestwood Equity

Limited Partners. A summary of CEQP’s limited partner quarterly cash distributions for the ~~six~~three months ended ~~June 30,~~March 31, 2023 and 2022 ~~and 2021~~ is presented below:

Record Date Payment Date Per Unit Rate
Cash Distributions
(in millions)
2022
February 7, 2022 February 14, 2022 $ 0.625 $ 60.9
May 6, 2022 May 13, 2022 $ 0.655 64.2
$ 125.1
2021
February 5, 2021 February 12, 2021 $ 0.625 $ 46.4
May 7, 2021 May 14, 2021 $ 0.625 39.3
$ 85.7


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



2022
February 7, 2022	February 14, 2022	$	0.625	$	60.9

On ~~July 14, 2022,~~April 20, 2023, we declared a distribution of $0.655 per limited partner unit to be paid on ~~August 12, 2022~~May 15, 2023 to unitholders of record on ~~August 5, 2022~~May 8, 2023 with respect to the quarter ended ~~June 30, 2022.~~March 31, 2023.

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Preferred Unitholders. During the ~~six~~three months ended ~~June 30,~~March 31, 2023 and 2022, ~~and 2021,~~ we paid cash distributions to our preferred unitholders of approximately ~~$30~~$15 million in both periods. On ~~July 14, 2022,~~April 20, 2023, the board of directors of our general partner authorized a cash distribution to our preferred unitholders of approximately $15 million with respect to the quarter ended ~~June 30, 2022.~~March 31, 2023.

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Crestwood Midstream

During the ~~six~~three months ended ~~June 30,~~March 31, 2023 and 2022, ~~and 2021,~~ Crestwood Midstream paid cash distributions of ~~$319.7~~$85.9 million and ~~$395.4~~$238.1 million to its partners.

On February 1, 2022, Crestwood Midstream received a non-cash contribution of approximately $1,075.1 million from Crestwood Equity related to net assets it acquired in conjunction with the merger with Oasis Midstream. In addition, on February 1, 2022, Crestwood Equity contributed cash acquired in conjunction with the merger with Oasis Midstream of approximately $14.9 million to Crestwood Midstream.

Non-Controlling Partner

Crestwood Niobrara 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 redemption value each period through net income attributable to non-controlling partner.

The following ~~table shows~~tables show the change in our non-controlling interest in subsidiary at ~~June 30,~~March 31, 2023 and 2022 ~~and 2021~~ (in millions):


Balance at December 31, ~~2021~~2022	$	~~434.6~~434.4

Distributions to non-controlling partner	~~(20.7)~~(10.3)
Net income attributable to non-controlling partner	~~20.5~~10.2
Balance at ~~June 30, 2022~~March 31, 2023	$	~~434.4~~434.3


Balance at December 31, ~~2020~~2021	$	~~432.7~~434.6

Distributions to non-controlling partner	~~(19.6)~~(10.3)
Net income attributable to non-controlling partner	~~20.4~~10.2
Balance at ~~June 30, 2021~~March 31, 2022	$	~~433.5~~434.5

In ~~July 2022,~~April 2023, Crestwood Niobrara paid a cash ~~distributions to Jackalope Holdings~~distribution of approximately $10.3 million to Jackalope Holdings with respect to the quarter ended ~~June 30, 2022.~~March 31, 2023.

Other

In February ~~2022,~~2023, Crestwood Equity issued ~~177,025~~245,929 performance units (the February 2023 Units) under the Crestwood Equity Partners LP ~~Long Term~~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 ~~June 30, 2022,~~March 31, 2023, we had total unamortized compensation expense of approximately ~~$4.2~~$5.7 million related to ~~these performance units.~~the February 2023 Units. During the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, we recognized compensation expense of ~~$0.5 million and $0.7~~$0.4 million related to ~~these performance units,~~the February 2023 Units, which is included in general and administrative expenses on our consolidated statements of operations.

During the ~~six~~three months ended ~~June 30, 2022, 206,017~~March 31, 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 ~~526,322~~217,702 common units during the ~~six~~three months ended ~~June 30, 2022~~March 31, 2023 related to those performance units.

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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

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being presented. Distributions declared in the period and undeclared distributions that accumulated during the period are added back to the numerator for purposes of the if-converted calculation. The dilutive effect of the stock-based compensation performance units is calculated using the treasury stock method which considers the impact to net income or loss attributable to Crestwood Equity Partners and limited partner units from the potential issuance of limited partner units.

We exclude potentially dilutive securities from the determination of diluted earnings per unit (as well as their related income statement impacts) when their impact is anti-dilutive. The following table summarizes information regarding the weighted-average of common units excluded during the three ~~and six~~ months ended ~~June 30,~~March 31, 2023 and 2022 ~~and 2021~~ (in millions):


		Three Months Ended		Six Months Ended			Three Months Ended
		June 30,		June 30,			March 31,
		2022	2021	2022	2021			2023	2022
Preferred units(1)	Preferred units(1)	7.1	7.1	7.1	7.1	Preferred units(1)		7.1	7.1
Crestwood Niobrara’s preferred units(1)	Crestwood Niobrara’s preferred units(1)	—	3.6	—	3.6	Crestwood Niobrara’s preferred units(1)		—	3.6
Unit-based compensation performance units(1)	Unit-based compensation performance units(1)	—	0.1	—	0.1	Unit-based compensation performance units(1)		—	0.3
Subordinated units(2)		—	—	—	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 ofadditional information regarding our performance units, see our ~~2021~~2022 Annual Report on Form 10-K.

~~(2)In March 2021, CEQP retired its subordinated units. For additional information regarding the retirement of the subordinated units, see Note 11.~~

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 six~~ months ended ~~ended June 30,~~March 31, 2023 and 2022 ~~and 2021~~ (in millions, except for per unit data):


		Three Months Ended				Six Months Ended					Three Months Ended
		June 30,				June 30,					March 31,
		2022		2021		2022		2021				2023		2022
Common unitholders’ interest in net income (loss)	Common unitholders’ interest in net income (loss)	$	14.1	$	(63.4)	$	11.1	$	(126.8)	Common unitholders’ interest in net income (loss)		$	16.4	$	(3.0)

Diluted net income (loss)	Diluted net income (loss)	$	14.1	$	(63.4)	$	11.1	$	(126.8)	Diluted net income (loss)		$	16.4	$	(3.0)

Weighted-average limited partners’ units outstanding - basic	Weighted-average limited partners’ units outstanding - basic	98.0		63.5		92.0		68.4		Weighted-average limited partners’ units outstanding - basic		105.2		86.0

Dilutive effect of Crestwood Niobrara preferred units	Dilutive effect of Crestwood Niobrara preferred units	4.5		—		4.5		—		Dilutive effect of Crestwood Niobrara preferred units		4.5		—
Dilutive effect of stock-based compensation performance units		0.1		—		0.2		—

Dilutive effect of unit-based compensation performance units										Dilutive effect of unit-based compensation performance units		0.1		—
Weighted-average limited partners’ units outstanding - diluted	Weighted-average limited partners’ units outstanding - diluted	102.6		63.5		96.7		68.4		Weighted-average limited partners’ units outstanding - diluted		109.8		86.0

Net income (loss) per limited partner unit:	Net income (loss) per limited partner unit:									Net income (loss) per limited partner unit:
Basic	Basic	$	0.14	$	(1.00)	$	0.12	$	(1.85)	Basic		$	0.16	$	(0.04)
Diluted	Diluted	$	0.14	$	(1.00)	$	0.11	$	(1.85)	Diluted		$	0.15	$	(0.04)

~~Note 13 – Segments~~

In conjunction with the divestiture of our Stagecoach Gas equity method investment as discussed in Note 5 and the merger with Oasis Midstream as discussed in Note 3, we modified our segments as of December 31, 2021 and, as a result, our financial statements reflect 3 operating and reporting segments: (i) gathering and processing north operations (includes our Arrow, Jackalope and Oasis Midstream Williston operations); (ii) gathering and processing south operations (includes our Marcellus, Barnett and Oasis Midstream Delaware Basin operations and our Crestwood Permian Basin Holdings LLC equity method investment); and (iii) storage and logistics operations (includes our crude oil, NGL and natural gas storage and logistics operations, and our Tres Holdings and PRBIC equity method investments). Our gathering and processing north and gathering and processing south segments were historically combined into one segment, and our storage and logistics segment was historically separated into a storage and transportation segment and a marketing, supply and logistics segment. The results of

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~~our operations described above are now reflected in the new respective segments for all periods presented.~~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 ~~compression, treating, processing~~ and disposal services to producers in the Williston Basin and Powder River Basin.

•Gathering and Processing South. Our gathering and processing south operations provide natural gas gathering, compression, treating and processing services, crude oil gathering services and produced water gathering and disposal services to producers in the ~~Marcellus, Barnett and~~ Delaware ~~basins.~~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 before income taxes, plus debt-related costs (net interest and debt expense) and depreciation, amortization and accretion expense. Below is a reconciliation of CEQP’s and CMLP’s net income ~~(loss)~~ to EBITDA (in millions):


		CEQP								CMLP										CEQP						CMLP
		Three Months Ended				Six Months Ended				Three Months Ended				Six Months Ended					Three Months Ended						Three Months Ended
		June 30,				June 30,				June 30,				June 30,					March 31,						March 31,
		2022		2021		2022		2021		2022		2021		2022		2021					2023		2022			2023		2022
Net income (loss)		$	39.4	$	(38.1)	$	61.6	$	(76.4)	$	(14.6)	$	(38.5)	$	5.6	$	(78.9)
Net income																		Net income			$	41.6	$	22.2		$	43.0	$	20.2
Add:	Add:																	Add:
Interest and debt expense, net	Interest and debt expense, net	40.1		35.1		76.2		71.1		40.1		35.1		76.2		71.1		Interest and debt expense, net			55.6		36.1			55.6		36.1
Loss on modification/extinguishment of debt		—		1.2		—		6.7		—		1.2		—		6.7

Provision for income taxes	Provision for income taxes	0.3		0.1		0.3		—		0.2		0.1		0.2		—		Provision for income taxes			0.3		—			0.3		—
Depreciation, amortization and accretion	Depreciation, amortization and accretion	80.6		58.8		155.4		118.0		83.0		62.2		161.2		125.0		Depreciation, amortization and accretion			81.4		74.8			81.3		78.2
EBITDA	EBITDA	$	160.4	$	57.1	$	293.5	$	119.4	$	108.7	$	60.1	$	243.2	$	123.9	EBITDA			$	178.9	$	133.1		$	180.2	$	134.5

The following tables summarize CEQP’s and CMLP’s reportable segment data for the three ~~and six~~ months ended ~~June 30,~~March 31, 2023 and 2022 ~~and 2021~~ (in millions). Intersegment revenues included in the following tables are accounted for as arms-length transactions that apply our revenue recognition policy described in our ~~2021~~2022 Annual Report on Form 10-K. Included in earnings ~~(loss)~~ from unconsolidated affiliates, net reflected in the tables below was approximately ~~$4.9~~$2.5 million and ~~$48.1~~$4.6 million of our proportionate share of interest expense, depreciation and amortization expense ~~goodwill impairments~~ and gains (losses) on long-lived assets, net recorded by our equity investments for the three months ended ~~June 30, 2022~~March 31, 2023 and ~~2021 and $9.5 million and $177.5 million for the six months ended June 30, 2022 and 2021.~~2022.

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Segment EBITDA Information


		Three Months Ended June 30, 2022											Three Months Ended March 31, 2023
		Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total			Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream	Crestwood Midstream											Crestwood Midstream
Revenues	Revenues	$	279.4	$	35.3	$	1,133.3	$	—	$	1,448.0	Revenues	$	215.4	$	130.9	$	916.8	$	—	$	1,263.1
Intersegment revenues		151.6		—		(151.6)		—		—
Intersegment revenues, net												Intersegment revenues, net	99.0		34.2		(133.2)		—		—
Costs of product/services sold	Costs of product/services sold	250.8		0.6		961.8		—		1,213.2		Costs of product/services sold	152.4		108.5		736.5		—		997.4
Operations and maintenance expense	Operations and maintenance expense	27.5		7.6		11.5		—		46.6		Operations and maintenance expense	29.3		15.1		12.2		—		56.6
General and administrative expense	General and administrative expense	—		—		—		25.0		25.0		General and administrative expense	—		—		—		30.2		30.2
Gain (loss) on long-lived assets, net												Gain (loss) on long-lived assets, net	0.1		(0.8)		—		0.3		(0.4)

Loss on long-lived assets, net		—		(60.4)		(0.1)		—		(60.5)

Earnings from unconsolidated affiliates, net	Earnings from unconsolidated affiliates, net	—		4.8		1.2		—		6.0		Earnings from unconsolidated affiliates, net	—		0.3		1.4		—		1.7
Crestwood Midstream EBITDA	Crestwood Midstream EBITDA	$	152.7	$	(28.5)	$	9.5	$	(25.0)	$	108.7	Crestwood Midstream EBITDA	$	132.8	$	41.0	$	36.3	$	(29.9)	$	180.2
Crestwood Equity	Crestwood Equity											Crestwood Equity
General and administrative expense	General and administrative expense	—		—		—		1.5		1.5		General and administrative expense	—		—		—		1.4		1.4
Elimination of loss on long-lived assets(1)		—		53.3		—		—		53.3
Other expense, net		—		—		—		(0.1)		(0.1)

Other income, net												Other income, net	—		—		—		0.1		0.1
Crestwood Equity EBITDA	Crestwood Equity EBITDA	$	152.7	$	24.8	$	9.5	$	(26.6)	$	160.4	Crestwood Equity EBITDA	$	132.8	$	41.0	$	36.3	$	(31.2)	$	178.9

~~(1)~~Represents the elimination of the loss on long-lived assets recorded by CMLP related to the sale of our assets in the Barnett Shale. For a further discussion of this loss on long-lived assets, see Note 3.

Three Months Ended June 30, 2021
Gathering and Processing North Gathering and Processing South Storage and Logistics Corporate Total
Crestwood Midstream
Revenues $ 148.6 $ 24.7 $ 756.3 $ — $ 929.6
Intersegment revenues 84.2 — (84.2) — —
Costs of product/services sold 120.5 0.1 676.6 — 797.2
Operations and maintenance expense 9.0 5.7 11.1 — 25.8
General and administrative expense — — — 19.7 19.7
Gain on long-lived assets, net 0.3 — — — 0.3
Earnings (loss) from unconsolidated affiliates, net — 1.0 (28.1) — (27.1)
Crestwood Midstream EBITDA $ 103.6 $ 19.9 $ (43.7) $ (19.7) $ 60.1
Crestwood Equity
General and administrative expense — — — 3.1 3.1
Other income, net — — — 0.1 0.1
Crestwood Equity EBITDA $ 103.6 $ 19.9 $ (43.7) $ (22.7) $ 57.1

~~Table of Contents~~

Six Months Ended June 30, 2022
Gathering and Processing North Gathering and Processing South Storage and Logistics Corporate Total
Crestwood Midstream
Revenues $ 514.6 $ 66.0 $ 2,451.2 $ — $ 3,031.8
Intersegment revenues 279.0 — (279.0) — —
Costs of product/services sold 456.4 — 2,121.2 — 2,577.6
Operations and maintenance expense 51.2 14.3 23.5 — 89.0
General and administrative expense — — — 66.7 66.7
Loss on long-lived assets, net — (60.2) (4.1) — (64.3)
Earnings from unconsolidated affiliates, net — 7.4 1.6 — 9.0
Crestwood Midstream EBITDA $ 286.0 $ (1.1) $ 25.0 $ (66.7) $ 243.2
Crestwood Equity
General and administrative expense — — — 3.2 3.2
Elimination of loss on long-lived assets(1)
— 53.3 — — 53.3
Other income, net — — — 0.2 0.2
Crestwood Equity EBITDA $ 286.0 $ 52.2 $ 25.0 $ (69.7) $ 293.5


		Six Months Ended June 30, 2021											Three Months Ended March 31, 2022
		Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total			Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream	Crestwood Midstream											Crestwood Midstream
Revenues	Revenues	$	278.4	$	49.3	$	1,634.6	$	—	$	1,962.3	Revenues	$	235.2	$	30.7	$	1,317.9	$	—	$	1,583.8
Intersegment revenues		189.5		—		(189.5)		—		—
Intersegment revenues, net												Intersegment revenues, net	127.4		—		(127.4)		—		—
Costs of product/services sold	Costs of product/services sold	236.7		0.4		1,373.9		—		1,611.0		Costs of product/services sold	205.6		(0.6)		1,159.4		—		1,364.4
Operations and maintenance expense	Operations and maintenance expense	24.1		12.0		22.5		—		58.6		Operations and maintenance expense	23.7		6.7		12.0		—		42.4
General and administrative expense	General and administrative expense	—		—		—		36.9		36.9		General and administrative expense	—		—		—		41.7		41.7
Gain (loss) on long-lived assets, net	Gain (loss) on long-lived assets, net	0.1		(1.3)		0.1		—		(1.1)		Gain (loss) on long-lived assets, net	—		0.2		(4.0)		—		(3.8)
Earnings (loss) from unconsolidated affiliates, net		—		0.2		(131.0)		—		(130.8)
Earnings from unconsolidated affiliates, net												Earnings from unconsolidated affiliates, net	—		2.6		0.4		—		3.0
Crestwood Midstream EBITDA	Crestwood Midstream EBITDA	$	207.2	$	35.8	$	(82.2)	$	(36.9)	$	123.9	Crestwood Midstream EBITDA	$	133.3	$	27.4	$	15.5	$	(41.7)	$	134.5
Crestwood Equity	Crestwood Equity											Crestwood Equity
General and administrative expense	General and administrative expense	—		—		—		4.6		4.6		General and administrative expense	—		—		—		1.7		1.7
Other income, net	Other income, net	—		—		—		0.1		0.1		Other income, net	—		—		—		0.3		0.3
Crestwood Equity EBITDA	Crestwood Equity EBITDA	$	207.2	$	35.8	$	(82.2)	$	(41.4)	$	119.4	Crestwood Equity EBITDA	$	133.3	$	27.4	$	15.5	$	(43.1)	$	133.1

Other Segment Information


		CEQP				CMLP					CEQP				CMLP
		June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021			March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022
Total Assets	Total Assets									Total Assets
Gathering and Processing North	Gathering and Processing North	$	4,082.7	$	2,408.0	$	4,082.7	$	2,408.0	Gathering and Processing North	$	3,950.5	$	4,003.6	$	3,950.5	$	4,003.6
Gathering and Processing South	Gathering and Processing South	1,006.2		886.5		1,077.9		1,017.4		Gathering and Processing South	1,455.9		1,473.0		1,455.9		1,473.0
Storage and Logistics	Storage and Logistics	1,091.7		1,125.1		1,091.7		1,125.1		Storage and Logistics	945.3		1,057.6		945.3		1,057.6
Corporate	Corporate	22.2		26.1		16.4		20.7		Corporate	37.6		32.8		32.1		27.2
Total Assets		$	6,202.8	$	4,445.7	$	6,268.7	$	4,571.2

Total assets										Total assets	$	6,389.3	$	6,567.0	$	6,383.8	$	6,561.4

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Note 14 - Revenues

Contract Assets and Contract Liabilities

Our contract assets and contract liabilities are reported in a net position on a contract-by-contract basis at the end of each reporting period. Our receivables related to our revenue contracts accounted for under ~~ASU~~Accounting Standards Update 2014-09, Revenue from Contracts with Customers (Topic 606) totaled ~~$386.4~~$340.0 million and ~~$331.0~~$368.2 million at ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~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 1514 years.

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


		June 30, 2022		December 31, 2021			March 31, 2023		December 31, 2022
Contract assets (non-current)	Contract assets (non-current)	$	1.1	$	1.3	Contract assets (non-current)	$	5.2	$	5.4
Contract liabilities (current)(1)	Contract liabilities (current)(1)	$	11.9	$	10.7	Contract liabilities (current)(1)	$	13.8	$	11.7
Contract liabilities (non-current)(1)	Contract liabilities (non-current)(1)	$	203.7	$	187.1	Contract liabilities (non-current)(1)	$	205.9	$	212.3

(1)During the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, we recognized revenues of approximately ~~$3.7 million and $7.2~~$8.0 million that were previously included in contract liabilities at December 31, ~~2021.~~2022. The remaining change in our contract liabilities during the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 2023 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 ~~June 30, 2022~~March 31, 2023 (in millions):


Remainder of 2022		$	47.6
2023		70.4
Remainder of 2023				Remainder of 2023	$	45.2
2024	2024	45.8		2024	42.1
2025	2025	3.2		2025	2.0
2026	2026	0.5		2026	0.6
2027				2027	0.5
Thereafter	Thereafter	1.3		Thereafter	0.6
Total	Total	$	168.8	Total	$	91.0

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 six~~ months ended ~~June 30,~~March 31, 2023 and 2022 ~~and 2021~~ (in millions). We believe this summary best depicts how the nature, amount, timing and uncertainty of our revenues and cash flows are affected by economic factors. Our non-Topic 606 revenues presented in the tables below primarily represents revenues related to our commodity-based derivatives.

Table of Contents


		Three Months Ended June 30, 2022											Three Months Ended March 31, 2023
		Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total			Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues	Topic 606 revenues											Topic 606 revenues
Gathering	Gathering											Gathering
Natural gas	Natural gas	$	32.9	$	24.5	$	—	$	—	$	57.4	Natural gas	$	33.6	$	4.3	$	—	$	—	$	37.9
Crude oil	Crude oil	14.1		1.9		—		—		16.0		Crude oil	14.2		1.9		—		—		16.1
Water	Water	41.2		3.3		—		—		44.5		Water	42.5		8.6		—		—		51.1
Processing	Processing											Processing
Natural gas	Natural gas	19.7		1.2		—		—		20.9		Natural gas	19.2		5.4		—		—		24.6

Compression
Natural gas		—		3.1		—		—		3.1

Storage	Storage											Storage
Crude oil	Crude oil	0.6		—		0.3		(0.1)		0.8		Crude oil	0.6		—		—		(0.1)		0.5
NGLs	NGLs	—		—		1.9		—		1.9		NGLs	—		—		2.2		—		2.2
Pipeline	Pipeline											Pipeline
Crude oil	Crude oil	—		—		0.4		—		0.4		Crude oil	1.1		0.2		0.4		—		1.7
NGLs	NGLs	—		—		0.1		—		0.1		NGLs	—		5.2		0.1		(5.2)		0.1
Transportation	Transportation											Transportation
Crude oil		1.5		0.3		—		(0.1)		1.7

NGLs	NGLs	—		—		5.5		—		5.5		NGLs	—		—		5.8		—		5.8

Rail Loading												Rail Loading
Crude oil												Crude oil	—		—		0.2		—		0.2

Product Sales	Product Sales											Product Sales
Natural gas	Natural gas	95.6		0.6		160.9		(73.5)		183.6		Natural gas	45.2		34.0		78.7		(65.0)		92.9
Crude oil	Crude oil	145.9		—		393.5		(12.9)		526.5		Crude oil	109.3		0.1		278.8		(30.0)		358.2
NGLs	NGLs	77.5		—		461.2		(65.0)		473.7		NGLs	46.9		105.9		404.3		(32.9)		524.2
Water	Water	1.3		—		—		—		1.3		Water	1.0		—		—		—		1.0
Other	Other	0.4		—		—		—		0.4		Other	0.3		—		0.1		—		0.4
Total Topic 606 revenues	Total Topic 606 revenues	430.7		34.9		1,023.8		(151.6)		1,337.8		Total Topic 606 revenues	313.9		165.6		770.6		(133.2)		1,116.9
Non-Topic 606 revenues	Non-Topic 606 revenues	0.3		0.4		109.5		—		110.2		Non-Topic 606 revenues	0.5		(0.5)		146.2		—		146.2
Total revenues	Total revenues	$	431.0	$	35.3	$	1,133.3	$	(151.6)	$	1,448.0	Total revenues	$	314.4	$	165.1	$	916.8	$	(133.2)	$	1,263.1

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Three Months Ended June 30, 2021
Gathering and Processing North Gathering and Processing South Storage and Logistics Intersegment Elimination Total
Topic 606 revenues
Gathering
Natural gas $ 13.6 $ 19.7 $ — $ — $ 33.3
Crude oil 18.4 — — — 18.4
Water 22.7 — — — 22.7
Processing
Natural gas 6.1 1.2 — — 7.3
Compression
Natural gas — 3.7 — — 3.7
Storage
Crude oil 0.1 — 0.1 (0.1) 0.1
NGLs — — 2.4 — 2.4
Pipeline
Crude oil — — 0.6 — 0.6
NGLs — — 0.1 — 0.1
Transportation
Crude oil 0.4 — — — 0.4
NGLs — — 4.2 — 4.2
Rail Loading
Crude oil — — 1.2 — 1.2
Product Sales
Natural gas 26.7 0.1 44.3 (26.8) 44.3
Crude oil 101.7 — 344.4 (14.7) 431.4
NGLs 42.9 — 304.8 (42.6) 305.1
Other — — 0.7 — 0.7
Total Topic 606 revenues 232.6 24.7 702.8 (84.2) 875.9
Non-Topic 606 revenues 0.2 — 53.5 — 53.7
Total revenues $ 232.8 $ 24.7 $ 756.3 $ (84.2) $ 929.6

~~Table of Contents~~

Six Months Ended June 30, 2022
Gathering and Processing North Gathering and Processing South Storage and Logistics Intersegment Elimination Total
Topic 606 revenues
Gathering
Natural gas $ 58.8 $ 46.9 $ — $ — $ 105.7
Crude oil 28.9 2.9 — — 31.8
Water 75.9 5.5 — — 81.4
Processing
Natural gas 34.1 2.3 — — 36.4
Compression
Natural gas — 6.6 — — 6.6
Storage
Crude oil 1.1 — 0.3 (0.2) 1.2
NGLs — — 4.7 — 4.7
Pipeline
Crude oil — — 0.9 — 0.9
NGLs — — 0.1 — 0.1
Transportation
Crude oil 2.7 0.4 — (0.1) 3.0
NGLs — — 11.3 — 11.3
Rail Loading
Crude oil — — 0.4 — 0.4
Product Sales
Natural gas 159.5 0.9 259.6 (125.6) 294.4
Crude oil 274.0 — 767.5 (24.1) 1,017.4
NGLs 154.4 — 1,093.9 (129.0) 1,119.3
Water 2.9 — — — 2.9
Other 0.6 — 0.3 — 0.9
Total Topic 606 revenues 792.9 65.5 2,139.0 (279.0) 2,718.4
Non-Topic 606 revenues 0.7 0.5 312.2 — 313.4
Total revenues $ 793.6 $ 66.0 $ 2,451.2 $ (279.0) $ 3,031.8

~~Table of Contents~~


		Six Months Ended June 30, 2021											Three Months Ended March 31, 2022
		Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total			Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Intersegment Elimination		Total
Topic 606 revenues	Topic 606 revenues											Topic 606 revenues
Gathering	Gathering											Gathering
Natural gas	Natural gas	$	26.8	$	37.9	$	—	$	—	$	64.7	Natural gas	$	25.9	$	22.4	$	—	$	—	$	48.3
Crude oil	Crude oil	39.1		—		—		—		39.1		Crude oil	14.8		1.0		—		—		15.8
Water	Water	44.7		—		—		—		44.7		Water	34.7		2.2		—		—		36.9
Processing	Processing											Processing
Natural gas	Natural gas	11.9		2.4		—		—		14.3		Natural gas	14.4		1.1		—		—		15.5

Compression	Compression											Compression
Natural gas	Natural gas	—		8.4		—		—		8.4		Natural gas	—		3.5		—		—		3.5
Storage	Storage											Storage
Crude oil	Crude oil	0.2		—		0.3		(0.2)		0.3		Crude oil	0.5		—		—		(0.1)		0.4
NGLs	NGLs	—		—		6.1		—		6.1		NGLs	—		—		2.8		—		2.8
Pipeline	Pipeline											Pipeline
Crude oil	Crude oil	—		—		1.4		—		1.4		Crude oil	1.2		0.1		0.5		—		1.8
NGLs		—		—		0.1		—		0.1

Transportation	Transportation											Transportation
Crude oil		1.1		—		—		—		1.1

NGLs	NGLs	—		—		8.4		—		8.4		NGLs	—		—		5.8		—		5.8

Rail Loading	Rail Loading											Rail Loading
Crude oil	Crude oil	—		—		2.2		—		2.2		Crude oil	—		—		0.4		—		0.4

Product Sales	Product Sales											Product Sales
Natural gas	Natural gas	69.0		0.6		139.9		(69.0)		140.5		Natural gas	63.9		0.3		98.7		(52.1)		110.8
Crude oil	Crude oil	191.7		—		595.6		(37.4)		749.9		Crude oil	128.1		—		374.0		(11.2)		490.9
NGLs	NGLs	83.2		—		710.8		(82.9)		711.1		NGLs	76.9		—		632.7		(64.0)		645.6
Water												Water	1.6		—		—		—		1.6
Other	Other	—		—		0.9		—		0.9		Other	0.2		—		0.3		—		0.5
Total Topic 606 revenues	Total Topic 606 revenues	467.7		49.3		1,465.7		(189.5)		1,793.2		Total Topic 606 revenues	362.2		30.6		1,115.2		(127.4)		1,380.6
Non-Topic 606 revenues	Non-Topic 606 revenues	0.2		—		168.9		—		169.1		Non-Topic 606 revenues	0.4		0.1		202.7		—		203.2
Total revenues	Total revenues	$	467.9	$	49.3	$	1,634.6	$	(189.5)	$	1,962.3	Total revenues	$	362.6	$	30.7	$	1,317.9	$	(127.4)	$	1,583.8

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.

Prior to August 2021, Crestwood Holdings indirectly owned our general partner and the affiliates of Crestwood Holdings and its owners were considered CEQP’s and CMLP’s related parties. With the completion For a further description of our ~~strategic transactions with Crestwood Holdings in August 2021, Crestwood Holdings and its affiliates are no longer considered~~ related ~~parties of CEQP and CMLP.~~party agreements, see our 2022 Annual Report on Form 10-K. During the ~~six~~three months ended ~~June 30, 2021,~~March 31, 2023, we paid approximately $0.5 million of capital expenditures to Applied Consultants, Inc., an affiliate of Crestwood Holdings. In addition, during the six months ended June 30, 2021, Crestwood Holdings allocated a $4.6 million reduction of unit-based compensation charges to CEQP and CMLP. Also, CEQP allocated approximately $0.2 million of its general and administrative costs to Crestwood Holdings during the six months ended June 30, 2021.

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). ~~For a further description of our related party agreements, see our 2021 Annual Report on Form 10-K.~~


		Three Months Ended				Six Months Ended					Three Months Ended
		June 30,				June 30,					March 31,
		2022		2021		2022		2021				2023		2022
Revenues at CEQP and CMLP(1)	Revenues at CEQP and CMLP(1)	$	134.2	$	13.2	$	231.9	$	18.1	Revenues at CEQP and CMLP(1)		$	—	$	97.7
Costs of product/services sold at CEQP and CMLP(2)	Costs of product/services sold at CEQP and CMLP(2)	$	113.1	$	25.4	$	181.6	$	66.5	Costs of product/services sold at CEQP and CMLP(2)		$	0.4	$	68.5
Operations and maintenance expenses at CEQP and CMLP charged to our unconsolidated affiliates(3)		$	5.0	$	6.0	$	9.8	$	11.7
Operations and maintenance expenses at CEQP and CMLP(3)										Operations and maintenance expenses at CEQP and CMLP(3)		$	2.4	$	4.8
General and administrative expenses charged by CEQP to CMLP, net(4)	General and administrative expenses charged by CEQP to CMLP, net(4)	$	7.5	$	6.6	$	15.0	$	12.5	General and administrative expenses charged by CEQP to CMLP, net(4)		$	8.9	$	7.5
General and administrative expenses at CEQP and CMLP(5)	General and administrative expenses at CEQP and CMLP(5)	$	0.4	$	—	$	1.3	$	—	General and administrative expenses at CEQP and CMLP(5)		$	—	$	0.9

(1)Includes (i) ~~$2.0 million and $3.6~~$59.0 million during the three ~~and six~~ months ended June 30, 2022 and $13.2 million and $18.1 million during the three and six months ended June 30, 2021 related to the sale of NGLs to a subsidiary of Crestwood Permian; (ii) $0.7 million and $1.2 million during the three and six months ended June 30, 2022 related to compressor leases with a subsidiary of Crestwood Permian; (iii) $76.9 million and $135.9 million during the three and six months ended June 30,March 31, 2022 primarily related to the sale of crude oil and NGLs to a subsidiary of ~~Oasis Petroleum; and (iv) $54.6 million and $91.2~~Chord; (ii) $36.6 million during the three ~~and six~~ months ended ~~June 30,~~March 31, 2022 primarily related to gathering and processing services ~~under agreements~~provided to a subsidiary of Chord; (iii) $1.6 million during the three months ended March 31, 2022 related to the sale of NGLs to a subsidiary of Crestwood Permian; and (iv) $0.5 million during the three months ended March 31, 2022 related to compressor leases with a subsidiary of ~~Oasis Petroleum.~~Crestwood Permian.

(2)Includes (i) ~~$71.4~~$0.3 million and ~~$107.6~~$0.9 million during the three ~~and six~~ months ended ~~June 30,~~March 31, 2023 and 2022 ~~and $14.8 million and $45.1~~primarily related to purchases of natural gas from a subsidiary of Tres Holdings; (ii) $0.1 million during the three ~~and six~~ months ended ~~June 30, 2021~~March 31, 2023 related to gathering services under agreements Crestwood Permian Basin; (iii) $31.4 million during the three months ended March 31, 2022 primarily related to purchases of NGLs from a subsidiary of Chord; and (iv) $36.2 million during the three months ended March 31, 2022 related to purchases of natural gas and NGLs from a subsidiary of Crestwood Permian; (ii) $0.5 million and $1.4 million during the three and six months ended June 30, 2022 and $0.3 million and $11.1 million during the three and six months ended June 30, 2021 primarily related to purchases of natural gas from a subsidiary of Tres Holdings; (iii) $41.2 million and $72.6 million during the three and six months ended June 30, 2022 primarily related to purchases of NGLs from a subsidiary of Oasis Petroleum; and (iv) $10.3 million during both the three and six months ended June 30, 2021 related to purchases of NGLs from Ascent Resources - Utica, LLC, an affiliate of Crestwood Holdings.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 three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, we charged ~~$1.1 million and $2.3~~$1.3 million to Tres Holdings and ~~$3.9 million and $7.5~~$1.1 million to Crestwood ~~Permian.~~Permian Basin. During the three ~~and six~~ months ended ~~June 30, 2021,~~March 31, 2022, we charged ~~$1.6 million and $3.3 million to Stagecoach Gas,~~ $1.2 ~~million and $2.4~~ million to Tres Holdings and ~~$3.2 million and $6.0~~$3.6 million to Crestwood Permian.

(4)Includes ~~$8.6~~$10.0 million and ~~$17.2~~$8.6 million of unit-based compensation charges allocated from CEQP to CMLP during the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 2023 and ~~$7.6 million and $14.5 million for the three and six months ended June 30, 2021.~~2022. In addition, includes $1.1 ~~million and $2.2~~ million of CMLP’s general and administrative costs allocated to CEQP during both the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 2023 and ~~$1.0 million and $2.0 million for the three and six months ended June 30, 2021.~~2022.

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

The following table shows ~~balances with~~accounts receivable and accounts payable from our affiliates ~~which are reflected in our consolidated balance sheets~~ (in millions):

June 30,
2022 December 31,
2021
Accounts receivable at CEQP and CMLP $ 72.6 $ 8.2
Accounts payable at CEQP and CMLP $ 32.6 $ 12.0

~~Note 16– Subsequent Events~~

~~Sendero Acquisition~~. On July 11, 2022, we acquired Sendero Midstream Partners, LP (Sendero), a privately-held midstream company, for approximately $600 million (Sendero Acquisition). Sendero’s assets are located in Eddy County, New Mexico and are comprised of 350 million cubic feet per day (MMcf/d) of processing capacity, approximately 140 miles of natural gas gathering lines and more than 53,000 horsepower of field gathering compression. We will account for the Sendero Acquisition as a business combination using the acquisition method of accounting. We are completing our analysis of the purchase price consideration and estimating the fair value of the assets acquired and liabilities assumed in connection with the Sendero Acquisition, which is primarily comprised of property, plant and equipment, intangible assets, and goodwill, however, due to the timing of the acquisition, we are unable to provide amounts recognized as of the acquisition date for these major classes of assets and liabilities acquired. During the three and six months ended June 30, 2022, we recognized approximately $0.9 million of transaction costs related to the Sendero Acquisition, which are included in general and administrative expenses in our consolidated statements of operations.

~~Crestwood Permian Acquisition~~. On July 11, 2022 we acquired First Reserve Management, L.P.’s (First Reserve) 50% equity interest in Crestwood Permian in exchange for approximately 11.3 million newly issued CEQP common units (Crestwood Permian Acquisition). The acquisition of this equity interest results in us owning 100% of the equity interests in Crestwood


	March 31, 2023		December 31, 2022
Accounts receivable at CEQP and CMLP	$	0.3	$	1.6
Accounts payable at CEQP and CMLP	$	0.7	$	3.0

~~Table of Contents~~

Permian and we anticipate that we will consolidate Crestwood Permian beginning in July 2022. We will account for the Crestwood Permian Acquisition as a business combination using the acquisition method of accounting. We are completing our analysis of the purchase price consideration and estimating the fair value of the assets acquired and liabilities assumed in connection with the Crestwood Permian Acquisition, which is primarily comprised of property, plant and equipment, intangible assets, goodwill, an equity method investment and long-term debt, however, due to the timing of the acquisition, we are unable to provide amounts recognized as of the acquisition date for these major classes of assets and liabilities acquired. During the three and six months ended June 30, 2022, we recognized approximately $0.2 million of transaction costs related to the Crestwood Permian Acquisition, which are included in general and administrative expenses in our consolidated statements of operations.

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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 ~~the~~ 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 ~~2021~~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 ~~(OPEC)~~ and other oil-producing countries to agree and maintain oil price and production controls;

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

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

•~~interest rates;~~

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

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

For additional factors that could cause actual results to be materially different from those described in the forward-looking statements above, see Part I, Item 1A. Risk Factors of our ~~2021~~2022 Annual Report on Form 10-K.

Outlook and Trends

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

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~~We have taken~~On February 20, 2023, we and Brookfield entered into an agreement with a ~~number~~third party to sell each of our respective interests in Tres Holdings for total consideration of approximately $335 million, plus working capital adjustments. The sale was completed on April 3, 2023 and largely completes our strategic ~~steps~~realignment to ~~better position the Company as a stronger, better capitalized company that can accretively grow cash flows and as an industry leader in Environmental, Social and Governance (ESG) efforts.~~

We continue to drive our long-term growth strategy through disciplined capital investments utilizing our current financial flexibility, and on February 1, 2022, we acquired Oasis Midstream in an equity and cash transaction valued at approximately $1.8 billion. Pursuant to the merger agreement, Oasis Petroleum received $150 million in cash plus 20.9 million newly issued CEQP common units in exchange for its 33.8 million common units held in Oasis Midstream. In addition, Oasis Midstream’s public unitholders received 12.9 million newly issued CEQP common units in exchange for the 14.8 million Oasis Midstream common units held by them. Additionally, under the merger agreement, Oasis Petroleum received a $10 million cash payment for its ownershipdivest of the general partner of Oasis Midstream. This transaction further solidifies Crestwood’s competitive position in the Williston Basin with exposure to approximately 1,200 drilling locations and 535,000 dedicated acres and expands the Company’s relationship with Oasis Petroleum. Additionally, Oasis Midstream’s Wild Basin gathering and processing assets are highly complementary with our Arrow gathering system and Bear Den processing facility which provides for immediate opportunities to drive cost savings and commercial synergies and better utilization of available gas processing capacity.non-core assets.

In ~~July 2022,~~2023, we completed a series of strategic transactions including (i) the acquisition of Sendero for $600 million, (ii) the acquisition of First Reserve’s 50% equity interest in Crestwood Permian in exchange for 11.3 million CEQP common units, and (iii) the divestiture ofplan to continue executing on our Barnett Shale assets for approximately $290 million. The Sendero Acquisition adds more than 75,000 dedicated acres and over 1,200 drilling locations in the Delaware Basin. In addition, Sendero’s assets are highly complementary to Crestwood Permian’s Willow Lake system and can be integrated with minimal capital investment, enabling the Company to capture substantial cost and commercial synergies and will result in approximately 550 MMcf/d of processing capacity. The acquisition of Sendero and First Reserve’s 50% equity interest in the Crestwood Permian joint venture significantly increases the Company’s position in the Delaware Basin.

The divestiture of the Cowtown, Lake Arlington and Alliance systems will represent a full exit of our operations in the Barnett Shale and allows the Company to focus on building and optimizing its gathering and processing positions in the Williston, Delaware and Powder River Basins which best positions the Company to deliver long-term value to its unitholders.

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

~~Recent Developments~~

~~Bakken DAPL Matter.~~ In July 2020, a U.S. District Court (District Court) ordered the Dakota Access Pipeline (DAPL) to cease operation based on an alleged procedural permitting failure. On August 5, 2020, the U.S. Court of Appeals for the District of Columbia Circuit (D.C. Circuit) stayed the DAPL shutdown, and subsequently issued an opinion upholding the District Court’s decision on the merits, but not prohibiting DAPL’s continued operation. The plaintiffs sought another injunction against DAPL’s operation, which was denied by the District Court in May 2021. As required by the District Court, the U.S. Army Corps of Engineers is currently conducting an environmental impact statement, which is currently expected to be complete in September 2022. We expect DAPL will remain in operation while the environmental impact statement is being completed.

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

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

~~Table of Contents~~

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

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

How We Evaluate Our Operations

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

EBITDA and Adjusted EBITDA - We believe that EBITDA and Adjusted EBITDA are widely accepted financial indicators of a company’s operational performance and its ability to incur and service debt, fund capital expenditures and make distributions. We believe that EBITDA and Adjusted EBITDA are useful to our investors because it allows them to use the same performance measure analyzed internally by our management to evaluate the performance of our businesses and investments without regard to the manner in which they are financed or our capital structure. EBITDA is defined as income before income taxes, plus debt-related costs (interest and debt expense, ~~net and loss on modification/extinguishment of debt)~~net) and depreciation, amortization and accretion expense. Adjusted EBITDA considers the adjusted earnings impact of our unconsolidated affiliates by adjusting our equity earnings or losses from our unconsolidated affiliates to reflect our proportionate share (based on the distribution percentage) of their EBITDA, excluding gains and losses on long-lived assets and other impairments. Adjusted EBITDA also considers the impact of certain significant items, such as unit-based compensation charges, gains or losses on long-lived assets, ~~impairments of goodwill,~~ third party costs incurred related to potential and completed acquisitions, certain environmental remediation costs, the change in fair value of commodity inventory-related derivative contracts, costs associated with the realignment and restructuring of our operations and corporate structure, and other transactions identified in a specific reporting period. The change in fair value of commodity inventory-related derivative contracts is considered in determining Adjusted EBITDA given that the timing of recognizing gains and losses on these derivative contracts differs from the recognition of revenue for the related underlying sale of inventory to which these derivatives relate. Changes in the fair value of other derivative contracts isare 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 items such as depreciation, amortization and accretion, interest and income taxes, which are necessary to maintain our business. EBITDA and Adjusted EBITDA should not be considered as alternatives to net income, operating cash flow or any other measure of financial performance presented in accordance with 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										Crestwood Equity						Crestwood Midstream
		Three Months Ended				Six Months Ended				Three Months Ended				Six Months Ended					Three Months Ended						Three Months Ended
		June 30,				June 30,				June 30,				June 30,					March 31,						March 31,
		2022		2021		2022		2021		2022		2021		2022		2021					2023		2022			2023		2022
Revenues	Revenues	$	1,448.0	$	929.6	$	3,031.8	$	1,962.3	$	1,448.0	$	929.6	$	3,031.8	$	1,962.3	Revenues			$	1,263.1	$	1,583.8		$	1,263.1	$	1,583.8
Costs of product/services sold	Costs of product/services sold	1,213.2		797.2		2,577.6		1,611.0		1,213.2		797.2		2,577.6		1,611.0		Costs of product/services sold			997.4		1,364.4			997.4		1,364.4
Operations and maintenance expense	Operations and maintenance expense	46.6		25.8		89.0		58.6		46.6		25.8		89.0		58.6		Operations and maintenance expense			56.6		42.4			56.6		42.4
General and administrative expense	General and administrative expense	26.5		22.8		69.9		41.5		25.0		19.7		66.7		36.9		General and administrative expense			31.6		43.4			30.2		41.7
Depreciation, amortization and accretion	Depreciation, amortization and accretion	80.6		58.8		155.4		118.0		83.0		62.2		161.2		125.0		Depreciation, amortization and accretion			81.4		74.8			81.3		78.2
(Gain) loss on long-lived assets, net		7.2		(0.3)		11.0		1.1		60.5		(0.3)		64.3		1.1
Loss on long-lived assets, net																		Loss on long-lived assets, net			0.4		3.8			0.4		3.8

Operating income	Operating income	73.9		25.3		128.9		132.1		19.7		25.0		73.0		129.7		Operating income			95.7		55.0			97.2		53.3
Earnings (loss) from unconsolidated affiliates, net		6.0		(27.1)		9.0		(130.8)		6.0		(27.1)		9.0		(130.8)
Earnings from unconsolidated affiliates, net																		Earnings from unconsolidated affiliates, net			1.7		3.0			1.7		3.0
Interest and debt expense, net	Interest and debt expense, net	(40.1)		(35.1)		(76.2)		(71.1)		(40.1)		(35.1)		(76.2)		(71.1)		Interest and debt expense, net			(55.6)		(36.1)			(55.6)		(36.1)
Loss on modification/extinguishment of debt		—		(1.2)		—		(6.7)		—		(1.2)		—		(6.7)
Other income (expense), net		(0.1)		0.1		0.2		0.1		—		—		—		—

Other income, net																		Other income, net			0.1		0.3			—		—
Provision for income taxes	Provision for income taxes	(0.3)		(0.1)		(0.3)		—		(0.2)		(0.1)		(0.2)		—		Provision for income taxes			(0.3)		—			(0.3)		—
Net income (loss)		39.4		(38.1)		61.6		(76.4)		(14.6)		(38.5)		5.6		(78.9)
Net income																		Net income			41.6		22.2			43.0		20.2
Add:	Add:																	Add:
Interest and debt expense, net	Interest and debt expense, net	40.1		35.1		76.2		71.1		40.1		35.1		76.2		71.1		Interest and debt expense, net			55.6		36.1			55.6		36.1
Loss on modification/extinguishment of debt		—		1.2		—		6.7		—		1.2		—		6.7

Provision for income taxes	Provision for income taxes	0.3		0.1		0.3		—		0.2		0.1		0.2		—		Provision for income taxes			0.3		—			0.3		—
Depreciation, amortization and accretion	Depreciation, amortization and accretion	80.6		58.8		155.4		118.0		83.0		62.2		161.2		125.0		Depreciation, amortization and accretion			81.4		74.8			81.3		78.2
EBITDA	EBITDA	160.4		57.1		293.5		119.4		108.7		60.1		243.2		123.9		EBITDA			178.9		133.1			180.2		134.5
Unit-based compensation charges	Unit-based compensation charges	8.6		7.6		17.2		9.9		8.6		7.6		17.2		9.9		Unit-based compensation charges			10.0		8.6			10.0		8.6
(Gain) loss on long-lived assets, net		7.2		(0.3)		11.0		1.1		60.5		(0.3)		64.3		1.1
Loss on long-lived assets, net																		Loss on long-lived assets, net			0.4		3.8			0.4		3.8

(Earnings) loss from unconsolidated affiliates, net		(6.0)		27.1		(9.0)		130.8		(6.0)		27.1		(9.0)		130.8
Earnings from unconsolidated affiliates, net																		Earnings from unconsolidated affiliates, net			(1.7)		(3.0)			(1.7)		(3.0)
Adjusted EBITDA from unconsolidated affiliates, net	Adjusted EBITDA from unconsolidated affiliates, net	10.9		21.0		18.5		46.7		10.9		21.0		18.5		46.7		Adjusted EBITDA from unconsolidated affiliates, net			4.2		7.6			4.2		7.6
Change in fair value of commodity inventory-related derivative contracts	Change in fair value of commodity inventory-related derivative contracts	(4.9)		32.6		0.8		2.1		(4.9)		32.6		0.8		2.1		Change in fair value of commodity inventory-related derivative contracts			(3.5)		5.7			(3.5)		5.7
Significant transaction and environmental related costs and other items	Significant transaction and environmental related costs and other items	3.5		0.6		20.5		1.1		3.5		(1.4)		20.5		(1.1)		Significant transaction and environmental related costs and other items			4.3		17.0			4.3		17.0
Adjusted EBITDA	Adjusted EBITDA	$	179.7	$	145.7	$	352.5	$	311.1	$	181.3	$	146.7	$	355.5	$	313.4	Adjusted EBITDA			$	192.6	$	172.8		$	193.9	$	174.2


		Crestwood Equity						Crestwood Midstream
	Three Months Ended						Three Months Ended
	March 31,						March 31,
			2023		2022			2023		2022
Net cash provided by operating activities			$	245.9	$	222.5		$	248.0	$	223.9
Net changes in operating assets and liabilities			(113.1)		(112.9)			(113.8)		(112.8)
Amortization of debt-related deferred costs and fair value adjustment			(0.8)		(0.8)			(0.8)		(0.8)
Interest and debt expense, net			55.6		36.1			55.6		36.1
Unit-based compensation charges			(10.0)		(8.6)			(10.0)		(8.6)
Loss on long-lived assets, net			(0.4)		(3.8)			(0.4)		(3.8)



Earnings from unconsolidated affiliates, net, adjusted for cash distributions received			1.4		0.4			1.4		0.4
Deferred income taxes			—		0.1			(0.1)		—
Provision for income taxes			0.3		—			0.3		—
Other non-cash expense			—		0.1			—		0.1
EBITDA			178.9		133.1			180.2		134.5
Unit-based compensation charges			10.0		8.6			10.0		8.6
Loss on long-lived assets, net			0.4		3.8			0.4		3.8



Earnings from unconsolidated affiliates, net			(1.7)		(3.0)			(1.7)		(3.0)
Adjusted EBITDA from unconsolidated affiliates, net			4.2		7.6			4.2		7.6
Change in fair value of commodity inventory-related derivative contracts			(3.5)		5.7			(3.5)		5.7
Significant transaction and environmental related costs and other items			4.3		17.0			4.3		17.0
Adjusted EBITDA			$	192.6	$	172.8		$	193.9	$	174.2

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Crestwood Equity Crestwood Midstream
Three Months Ended Six Months Ended Three Months Ended Six Months Ended
June 30, June 30, June 30, June 30,
2022 2021 2022 2021 2022 2021 2022 2021
Net cash provided by operating activities $ 29.5 $ 35.0 $ 252.0 $ 293.5 $ 31.3 $ 38.0 $ 255.2 $ 297.2
Net changes in operating assets and liabilities 106.9 33.1 (6.0) (89.7) 106.9 33.2 (5.9) (88.8)
Amortization of debt-related deferred costs (0.4) (1.7) (1.2) (3.4) (0.4) (1.7) (1.2) (3.4)
Interest and debt expense, net 40.1 35.1 76.2 71.1 40.1 35.1 76.2 71.1
Unit-based compensation charges (8.6) (7.6) (17.2) (9.9) (8.6) (7.6) (17.2) (9.9)
Gain (loss) on long-lived assets, net (7.2) 0.3 (11.0) (1.1) (60.5) 0.3 (64.3) (1.1)
Earnings (loss) from unconsolidated affiliates, net, adjusted for cash distributions received (0.2) (37.3) 0.2 (141.1) (0.2) (37.3) 0.2 (141.1)
Deferred income taxes — 0.1 0.1 0.1 (0.1) — (0.1) —
Provision for income taxes 0.3 0.1 0.3 — 0.2 0.1 0.2 —
Other non-cash income (expense) — — 0.1 (0.1) — — 0.1 (0.1)
EBITDA 160.4 57.1 293.5 119.4 108.7 60.1 243.2 123.9
Unit-based compensation charges 8.6 7.6 17.2 9.9 8.6 7.6 17.2 9.9
(Gain) loss on long-lived assets, net 7.2 (0.3) 11.0 1.1 60.5 (0.3) 64.3 1.1
(Earnings) loss from unconsolidated affiliates, net (6.0) 27.1 (9.0) 130.8 (6.0) 27.1 (9.0) 130.8
Adjusted EBITDA from unconsolidated affiliates, net 10.9 21.0 18.5 46.7 10.9 21.0 18.5 46.7
Change in fair value of commodity inventory-related derivative contracts (4.9) 32.6 0.8 2.1 (4.9) 32.6 0.8 2.1
Significant transaction and environmental related costs and other items 3.5 0.6 20.5 1.1 3.5 (1.4) 20.5 (1.1)
Adjusted EBITDA $ 179.7 $ 145.7 $ 352.5 $ 311.1 $ 181.3 $ 146.7 $ 355.5 $ 313.4

Segment Results

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

Three Months Ended Three Months Ended
June 30, 2022 June 30, 2021
Gathering and Processing North Gathering and Processing South Storage and Logistics Gathering and Processing North Gathering and Processing South Storage and Logistics
Revenues $ 279.4 $ 35.3 $ 1,133.3 $ 148.6 $ 24.7 $ 756.3
Intersegment revenues 151.6 — (151.6) 84.2 — (84.2)
Costs of product/services sold 250.8 0.6 961.8 120.5 0.1 676.6
Operations and maintenance expenses 27.5 7.6 11.5 9.0 5.7 11.1
Gain (loss) on long-lived assets, net — (60.4) (0.1) 0.3 — —
Earnings (loss) from unconsolidated affiliates, net — 4.8 1.2 — 1.0 (28.1)
Crestwood Midstream EBITDA $ 152.7 $ (28.5) $ 9.5 $ 103.6 $ 19.9 $ (43.7)
Elimination of loss on long-lived assets(1)
— 53.3 — $ — $ — $ —
Crestwood Equity EBITDA $ 152.7 $ 24.8 $ 9.5 $ 103.6 $ 19.9 $ (43.7)

~~Table of Contents~~

Six Months Ended Six Months Ended
June 30, 2022 June 30, 2021
Gathering and Processing North Gathering and Processing South Storage and Logistics Gathering and Processing North Gathering and Processing South Storage and Logistics
Revenues $ 514.6 $ 66.0 $ 2,451.2 $ 278.4 $ 49.3 $ 1,634.6
Intersegment revenues 279.0 — (279.0) 189.5 — (189.5)
Costs of product/services sold 456.4 — 2,121.2 236.7 0.4 1,373.9
Operations and maintenance expenses 51.2 14.3 23.5 24.1 12.0 22.5
Gain (loss) on long-lived assets, net — (60.2) (4.1) 0.1 (1.3) 0.1
Earnings (loss) from unconsolidated affiliates, net — 7.4 1.6 — 0.2 (131.0)
Crestwood Midstream EBITDA $ 286.0 $ (1.1) $ 25.0 $ 207.2 $ 35.8 $ (82.2)
Elimination of loss on long-lived assets(1)
— 53.3 — — — —
Crestwood Equity EBITDA $ 286.0 $ 52.2 $ 25.0 $ 207.2 $ 35.8 $ (82.2)


	Three Months Ended						Three Months Ended
	March 31, 2023						March 31, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Gathering and Processing North		Gathering and Processing South		Storage and Logistics
Revenues	$	215.4	$	130.9	$	916.8	$	235.2	$	30.7	$	1,317.9
Intersegment revenues	99.0		34.2		(133.2)		127.4		—		(127.4)
Costs of product/services sold	152.4		108.5		736.5		205.6		(0.6)		1,159.4
Operations and maintenance expenses	29.3		15.1		12.2		23.7		6.7		12.0
Gain (loss) on long-lived assets, net	0.1		(0.8)		—		—		0.2		(4.0)


Earnings from unconsolidated affiliates, net	—		0.3		1.4		—		2.6		0.4
EBITDA	$	132.8	$	41.0	$	36.3	$	133.3	$	27.4	$	15.5

Below is a discussion of the factors that impacted EBITDA by segment for the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 2023 compared to the same ~~periods~~period in ~~2021.~~2022.

Gathering and Processing North

EBITDA for our gathering and processing north segment ~~increased by approximately $49.1 million and $78.8 million~~was relatively flat during the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 2023 compared to the same ~~periods~~period in ~~2021. On February 1,~~ 2022, ~~we completed~~primarily due to the contribution of our Williston Basin operations acquired in conjunction with the merger with Oasis Midstream ~~and as a result, we began reflecting~~in February 2022, offset by the ~~financial results of Oasis Midstream’s Williston Basin operations~~decline in ~~our~~ gathering and processing ~~north segment. For a further discussion~~volumes and the impact of ~~this merger, see Item 1. Financial Statements, Note 3.~~lower commodity prices experienced by our Arrow operations during the three months ended March 31, 2023 compared to the same period in 2022.

Our gathering and processing north segment’s revenues ~~increased~~decreased by approximately ~~$198.2 million and $325.7~~$48.2 million during the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 2023 compared to the same ~~periods~~period in ~~2021,~~2022, while our costs of product/services sold ~~increased~~decreased by approximately $130.3 million and $219.7 million during those same periods. During the three and six months ended June 30, 2022, we recognized revenues of approximately $92.0 million and $155.5 million and product costs of approximately $28.3 million and $47.6 million, respectively, related to our Oasis Midstream Williston Basin operations. The remaining increases in our gathering and processing north segment’s revenues and costs of product/services sold$53.2 million. These decreases were primarily driven by our Arrow operations which experienced ~~higher~~a more than 30% decrease in the average commodity prices it received on ~~its agreements under which~~natural gas and NGLs it purchases and sells ~~crude oil~~pursuant to its gas gathering and ~~natural gas, partially offset by lower volumes due to unusual winter weather conditions experienced in April and early May 2022 that unfavorably impacted our operations and our customers’ operations~~processing agreements during the three ~~and six~~ months ended ~~June 30, 2022. During both the three and six months ended June 30, 2022, Arrow’s realized prices on its commodity sales increased by more than 50%~~March 31, 2023 compared to the same ~~periods~~period in ~~2021.~~2022. We manage our company-wide crude 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 decreased by ~~16%~~approximately 10% and ~~13%~~11%, respectively during the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 2023 compared to the same ~~periods~~period in ~~2021,~~2022 due to unusual winter weather conditions experienced at the end of 2022 and into early 2023. Partially offsetting the decrease in revenues described above was the impact of our Williston Basin operations acquired in conjunction with the merger with Oasis Midstream in February 2022, which experienced an increase in its ~~crude oil~~natural gas gathering and processing volumes ~~decreased by 32%~~of approximately 46% and 42%, respectively, during ~~both~~ the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 2023 compared to the same ~~periods~~period in ~~2021.~~2022.

Our gathering and processing north segment’s operations and maintenance expenses increased by approximately ~~$18.5 million and $27.1~~$5.6 million during the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 2023 compared to the same ~~periods~~period in ~~2021,~~2022, primarily due to our Williston Basin operations acquired in conjunction with the merger with Oasis Midstream ~~Williston Basin operations.~~

in February 2022.

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Gathering and Processing South

EBITDA for ~~CMLP’s~~our gathering and processing south segment ~~decreased~~increased by approximately ~~$48.4~~$13.6 million and $36.9 million during the three and six months ended June 30, 2022 compared to the same periods in 2021. CMLP’s gathering and processing south segment’s EBITDA was impacted by losses on long-lived assets we recorded during the three months ended ~~June 30, 2022 related~~March 31, 2023 compared to ~~our Barnett and legacy Granite Wash operations which are further described below. In addition, upon~~ the ~~completion of the merger with Oasis Midstream described above, we began reflecting the financial results of Oasis Midstream’s Delaware Basin operations~~same period in ~~our gathering and processing south segment.~~

2022. Our gathering and processing south segment’s revenues, costs of product/services sold and operations and maintenance expenses increased by approximately ~~$10.6~~$134.4 million, $109.1 million, and ~~$16.7~~$8.4 million, respectively, during the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 2023 compared to the same ~~periods~~period in ~~2021. During~~2022. These increases were primarily driven by the ~~three and six months ended June 30,~~impact of our Delaware Basin operations acquired during February 2022 ~~we recognized revenues of approximately $5.5 million and $8.8 million related to our~~in conjunction with the merger with Oasis Midstream, ~~Delaware Basin operations. The~~the acquisitions in July 2022 of Sendero Midstream Partners LP and the remaining ~~increase~~50% equity interest in Crestwood Permian, which increased our gathering and processing south segment’s revenues, ~~was primarily driven~~costs of product/services sold and operations and maintenance expenses by approximately $162.9 million, $109.3 million and $15.2 million, respectively.

Partially offsetting the ~~impact that higher commodity prices had on~~increases described above were the divestitures of our Barnett and Marcellus legacy, non-core operations during 2022, which decreased our gathering and processing ~~contracts whose realized prices are partially based on commodity prices,~~south segment’s revenues and ~~a 7% increase in our natural gas gathering volumes on our Barnett system~~operations and maintenance expenses by approximately $27.6 million and $6.6 million, respectively, during the ~~six~~three months ended ~~June 30, 2022~~March 31, 2023 compared to the same period in ~~2021. During the six months ended June 30, 2021, gathering volumes on our Barnett system were lower due to the extreme winter weather conditions experienced during that period.~~

Our gathering and processing south segment’s operations and maintenance expenses increased by approximately $1.9 million and $2.3 million during the three and six months ended June 30, 2022 compared to the same periods in 2021, primarily due to our Oasis Midstream Delaware Basin operations.

CMLP’s gathering and processing south segment’s EBITDA was impacted by a loss on long-lived assets of approximately $53.3 million during the three months ended June 30, 2022 related to our assets in the Barnett Shale which were sold on July 1, 2022. For a further discussion on the sale of our assets in the Barnett Shale, see Item 1. Financial Statements, Note 3. In addition, during the three months ended June 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.

Our gathering and processing south segment’s EBITDA was also impacted by ~~an increase~~a net decrease in ~~equity~~ earnings from unconsolidated affiliates of approximately ~~$3.8~~$2.3 million ~~and $7.2 million from~~during the three months ended March 31, 2023 compared to the same period in 2022, primarily due to the consolidation of our Crestwood Permian equity investment ~~during~~as a result of acquiring the ~~three and six months ended June 30, 2022 compared to the same periods~~remaining 50% equity interest in ~~2021. During the three and six months ended June 30, 2022,~~ Crestwood Permian ~~experienced an increase~~ in its natural gas gathering and processing revenues primarily due to the impact that higher commodity prices had on its gathering and processing contracts, and higher gathering and processing volumes which increased by more than 100% compared to the same periods in 2021.

EBITDA for CEQP’s gathering and processing south segment increased by approximately $4.9 million and $16.4 million during the three and six months ended June 30, 2022 compared to the same periods in 2021. The change in CEQP’s gathering and processing south segment’s EBITDA period over period was due to all of the factors discussed above for CMLP. However, CEQP did not record a loss on long-lived assets related to the reclassification of Barnett’s net assets to current assets held for sale due to historical impairments previously recorded on Barnett’s property, plant and equipment by CEQP, which is further discussed in Item 1. Financial Statements, Note 3.July 2022.

Storage and Logistics

EBITDA for our storage and logistics segment increased by approximately ~~$53.2 million and $107.2~~$20.8 million during the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 2023 compared to the same ~~periods~~period in ~~2021. Our~~2022, primarily driven by our NGL logistics operations which experienced an increase in demand for its storage and terminalling services during early 2023 due to unusual winter weather conditions in the Midwest and East Coast. Partially offsetting the increase in our NGL logistics ~~segment’s EBITDA for~~operations was the ~~three and six months ended June 30, 2021 was impacted by a reduction to the equity earnings from our Stagecoach Gas equity method investment as a result~~impact of ~~recording our proportionate share of a loss on long-lived assets (including goodwill) recorded by the equity method investee as further discussed~~lower commodity prices described below.

Our storage and logistics segment’s revenues increased by approximately $309.6 million and $727.1 million during the three and six months ended June 30, 2022 compared to the same periods in 2021, while our costs of product/services sold increased by approximately $285.2 million and $747.3 million during those same periods.

Our NGL marketing and logistics operations experienced ~~an increase~~a decrease in revenues ~~of approximately $193.6 million~~ and ~~$483.2 million during the three and six months ended June 30, 2022 compared to the same periods in 2021, and an increase in its~~ costs of product/services sold of approximately ~~$173.1~~$259.0 million and ~~$502.4~~$276.9 million, respectively, during ~~those~~the three months ended March 31, 2023 compared to the same ~~periods.~~period in 2022. These ~~increases~~decreases were primarily driven by ~~higher~~lower NGL prices during the three months ended March 31, 2023 as a result of overall ~~increases~~decreases in commodity prices during ~~2022~~early 2023 compared to ~~2021.~~the same period in 2022. Our

~~Table of Contents~~

NGL marketing and logistics operations’ costs of product/services sold ~~was impacted by~~decreased more than its revenues primarily due to the ~~effect that increasing~~increased demand for our NGL storage and terminalling operations described above and the impact of commodity prices on our assets and liabilities from price risk management ~~activities.~~activities that manage our company-wide crude oil, natural gas and NGL commodity price exposures. Included in our costs of product/services sold was a ~~loss~~gain of ~~$3.7 million and $51.3~~$7.2 million during the three ~~and six~~ months ended ~~June 30, 2022, and~~March 31, 2023 as compared to a loss of ~~$33.3 million and $41.4~~$47.6 million during the three ~~and six~~ months ended ~~June 30, 2021~~March 31, 2022 related to our price risk management activities. These losses resulted in our revenues increasing more than our costs of product/services sold during the three months ended June 30, 2022, while during the six months ended June 30, 2022, these losses resulted in our costs of product/services sold increasing more than our revenues.

Our crude oil and natural gas marketing operations experienced ~~an increase~~a decrease in its revenues and product costs of approximately ~~$118.5~~$147.3 million and ~~$247.4~~$146.1 million, respectively, during the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023 compared to the same ~~periods~~period in ~~2021, and an increase in product costs of approximately $111.5 million and $244.7 million during those same periods.~~2022. These ~~increases~~decreases were primarily driven by ~~higher~~lower crude oil purchases and sales as a result of ~~increases~~decreases in commodity prices during ~~2022~~the three months ended March 31, 2023 compared to ~~2021, as well as an increase~~the same period in ~~marketing activity surrounding our natural gas-related operations driven by higher natural gas prices.~~2022.

Our storage and logistics segment’s EBITDA during the three months ended March 31, 2022 was impacted by a loss on long-lived assets of approximately ~~$4.1~~$4.0 million ~~during the six months ended June 30, 2022~~ primarily due to the buyout of leases related to our exiting the crude oil railcar leasing business. ~~For a further discussion of this matter, see Item 1. Financial Statements, Note 10.~~

Our storage and transportation segment’s EBITDA was also impacted by ~~a net~~an increase in earnings from unconsolidated affiliates of approximately ~~$29.3 million and $132.6~~$1.0 million during the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 2023 compared to the same ~~periods~~period in 2021. During the three and six months ended June 30, 2021, our results included a loss from unconsolidated affiliates of approximately $28.0 million and $140.3 million from our Stagecoach Gas equity investment that was sold in mid-2021. This loss primarily related to a $35.5 million and $155.4 million reduction to the equity earnings recorded during the three and six months ended June 30, 2021 as a result of recording our proportionate share of a loss on long-lived assets (including goodwill) recorded by the equity method investee. In addition, our earnings from unconsolidated affiliates during the six months ended June 30, 2021 were also reduced by our proportionate share of transaction costs of approximately $3.0 million related to the sale of the Stagecoach Gas equity investment. For a further discussion of this matter, see Item 1. Financial Statements, Note 5.2022. During the three months ended ~~June 30, 2022,~~March 31, 2023, earnings from our Tres Holdings equity investment increased ~~by $1.4 million compared to the same period in 2021,~~ primarily due to ~~its ability to capture additional storage and transportation opportunities as a result of~~ higher ~~natural gas prices during 2022 compared to 2021. During the six months ended June 30, 2022, earnings from our~~revenues experienced by Tres Holdings ~~equity investment decreased by $7.3 million compared to the same period in 2021. During the six months ended June 30, 2021, Tres Holdings experienced higher revenues~~resulting from ~~natural gas inventory sales and~~ an increase in demand for its storage and transportation services ~~as a result of the unusually cold weather experienced during~~in early ~~2021.~~2023.

Table of Contents

Other EBITDA Results

General and Administrative Expenses.During the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, our general and administrative expenses ~~increased~~decreased by approximately $12 million compared to the same ~~periods~~period in ~~2021,~~2022, primarily due to ~~transactions~~transaction costs incurred in ~~conjunction~~connection with ~~the merger with Oasis Midstream. In addition, we also experienced higher unit-based compensation charges~~our strategic transactions executed during the three and six months ended June 30, 2022 compared to the same periods in 2021, primarily due to higher average awards outstanding under our long-term incentive plans. Crestwood Equity‘s increase in its general and administrative expenses was partially offset by transaction costs it recorded during 2021 in conjunction with the Crestwood Holdings Transactions discussed in Item 1. Financial Statements, Note 11.2022.

Items not affecting EBITDA include the following:

Depreciation, Amortization and Accretion Expense. During the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, our depreciation, amortization and accretion expense increased compared to the same ~~periods~~period in ~~2021,~~2022, primarily due to our acquisitions during 2022, partially offset by the ~~merger with Oasis Midstream.~~divestitures of our legacy Barnett and Marcellus operations during 2022.

Interest and Debt Expense, Net. During the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, our interest and debt expense, ~~related~~net increased by approximately $20 million compared to ~~our senior notes increased~~the same period in 2022, primarily due to the ~~April 2029~~2031 Senior Notes ~~assumed~~issued in ~~conjunction with~~January 2023 and higher interest rates on borrowings under the ~~merger with Oasis Midstream.~~CMLP Credit Facility during 2023 compared to 2022.

~~Table of Contents~~

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


		Three Months Ended				Six Months Ended					Three Months Ended
		June 30,				June 30,					March 31,
		2022		2021		2022		2021				2023		2022
Credit facility		$	5.3	$	5.4	$	8.7	$	8.9
Credit facilities										Credit facilities		$	11.6	$	3.4
Senior notes	Senior notes	35.1		27.0		67.2		56.8		Senior notes		44.1		32.1
Other		0.4		2.7		1.3		5.6
Other, net										Other, net		1.0		0.9
Gross interest and debt expense	Gross interest and debt expense	40.8		35.1		77.2		71.3		Gross interest and debt expense		56.7		36.4
Less: capitalized interest	Less: capitalized interest	0.7		—		1.0		0.2		Less: capitalized interest		1.1		0.3
Interest and debt expense, net	Interest and debt expense, net	$	40.1	$	35.1	$	76.2	$	71.1	Interest and debt expense, net		$	55.6	$	36.1

~~Loss on Extinguishment of Debt.~~ During the three and six months ended June 30, 2021, we recognized a loss on extinguishment of debt of approximately $1.2 million and $6.7 million in conjunction with the redemption of our 2023 Senior Notes.

Liquidity and Sources of Capital

Crestwood Equity is a holding company that derives all of its operating cash flow from its operating subsidiaries. Our principal sources of liquidity include cash generated by operating activities from our subsidiaries, distributions from our joint ventures, borrowings under the ~~Crestwood Midstream~~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, and service their outstanding indebtedness.~~expenditures. We believe our liquidity sources and operating cash flows are sufficient to address our future operating, debt service and capital requirements.

We make quarterly cash distributions to our common unitholders within approximately 45 days after the end of each fiscal quarter in an aggregate amount equal to our available cash for such quarter. We also pay quarterly cash distributions of approximately $15 million to our preferred unitholders and quarterly cash distributions of approximately $10 million to Crestwood ~~Niobrara LLC’s~~Niobrara’s non-controlling partner. The $434.3 million of preferred securities issued to Crestwood Niobrara’s non-controlling partner are redeemable by the non-controlling partner beginning in January 2024, and we believe we have adequate borrowing capacity under the Crestwood Midstream credit facility along with adequate other potential sources of capital to fund any such potential redemption.

On ~~July 14, 2022,~~April 20, 2023, we declared a quarterly cash distribution of $0.655 per unit to our common unitholders with respect to the ~~second~~first quarter of ~~2022,~~2023, which will be paid on ~~August 12, 2022.~~May 15, 2023. Our Board of Directors evaluates the level of distributions to our common and preferred unitholders every quarter and considers a wide range of strategic, commercial, operational and financial factors, including current and projected operating cash flows. We believe our operating cash flows will exceed cash distributions to our partners, preferred unitholders and non-controlling partner, and as a result, we will have adequate operating cash flows as a source of liquidity for our growth capital expenditures.

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

As of ~~June 30, 2022,~~March 31, 2023, we had ~~$812.2 million~~$1.1 billion of available capacity under the Crestwood Midstream credit facility, considering the most restrictive debt covenants in the credit agreement. ~~Upon the closing of the merger with Oasis Midstream on February 1, 2022, the Crestwood Midstream credit facility was increased to $1.5 billion.~~ As of ~~June 30, 2022,~~March 31, 2023, we were in compliance with all of our debt covenants applicable to ~~the~~our credit facility and senior notes. See ~~Part I,~~ Item 1. Financial Statements, Note 8 for a description of the covenants related to our credit facility. ~~In conjunction with the acquisition~~

Table of the First Reserve’s 50% equity interest in Crestwood Permian, we assumed Crestwood Permian’s credit facility, which provides for revolving loans, letters of credit and swing line loans in an aggregate principal amount of up to $230 million. In addition, the Crestwood Permian credit facility has an accordion feature that allows Crestwood Permian to increase the available borrowings under the facility by up to an additional $85 million, subject to certain conditions. As of July 11, 2022, outstanding borrowings under the Crestwood Permian credit facility were approximately $140.8 million.Contents

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

~~Table~~ In January 2023, Crestwood Midstream issued $600 million of ~~Contents~~

7.375% unsecured senior notes due 2031 (the 2031 Senior Notes). We used the 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 $178.3 million, including working capital adjustments, and we used the proceeds from the sale to repay amounts outstanding under the Crestwood Midstream credit facility.

Cash Flows

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


		Six Months Ended					Three Months Ended
		June 30,					March 31,
		2022		2021			2023		2022
Net cash provided by operating activities	Net cash provided by operating activities	$	252.0	$	293.5	Net cash provided by operating activities	$	245.9	$	222.5
Net cash provided by (used in) investing activities		$	(206.4)	$	1.9
Net cash used in investing activities						Net cash used in investing activities	$	(70.4)	$	(179.7)
Net cash used in financing activities	Net cash used in financing activities	$	(45.1)	$	(292.8)	Net cash used in financing activities	$	(174.4)	$	(44.2)

Operating Activities

Our ~~operating~~ cash flows ~~decreased~~from operating activities increased by approximately ~~$41.5~~$23.4 million during the ~~six~~three months ~~ended June 30, 2022~~March 31, 2023 compared to the same period in ~~2021.~~2022. The ~~decrease~~net increase was primarily driven by ~~lower net~~our gathering and processing operations acquired in the Williston and Delaware Basins during 2022, partially offset by a reduction in operating cash ~~inflow~~flows from ~~working capital of approximately $83.7 million primarily related to~~ our ~~storage~~Barnett and ~~logistics~~Marcellus operations which ~~was impacted by higher commodity prices and its impact on its price risk management activities.~~were divested during 2022. In addition, ~~we experienced higher~~our general and administrative expenses ~~of approximately $28.4 million~~decreased during the three months ended March 31, 2023 compared to the same period in 2022, primarily due to transaction costs ~~related to the merger~~incurred in connection with ~~Oasis Midstream. Partially offsetting these decreases was the contribution from the Oasis Midstream operations acquired on February 1,~~our strategic transactions executed during 2022.

Investing Activities

~~Acquisition~~. On February 1, 2022, we completed the merger with Oasis Midstream, which was valued at approximately $1.8 billion. We paid cash consideration of $160 million, net of cash acquired of approximately $14.9 million and issued approximately 33.8 million units to Oasis Midstream’s unitholders. See Item 1, Financial Statements, Note 3 for a further discussion of the merger.

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

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

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

~~As a result of the series of strategic transactions completed in July 2022, which include the acquisitions of Sendero~~Our growth and the remaining 50% equity interest in Crestwood Permian and the divestiture of our assets in the Barnett Shale, we currently estimate that our growth capital expenditures during 2022 will be approximately $220 million to $240 million. In addition, we expect to spend between approximately $30 million and $35 million on maintenance capital expenditures and approximately $5 million to $15 million on capital expenditures that are directly reimbursable ~~by our customers. Our growth~~ capital expenditures during the year will increase the services we can provide to our customers and the operating efficiencies of our systems. We expect to finance our capital expenditures with a combination of cash generated by our operating subsidiaries, distributions received from our equity investments and borrowings under our credit facility. Additional commitments or expenditures will be made at our discretion, and any discontinuation of the construction of these ~~construction~~ projects could result in less future operating cash flows and earnings.

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The following table summarizes our capital expenditures for the ~~six~~three months ended ~~June 30, 2022~~March 31, 2023 (in millions):


Growth capital(1)	$	~~66.8~~57.9
Maintenance capital	~~8.8~~6.9
Other(2)	~~2.6~~2.5
Purchases of property, plant and equipment	$	~~78.2~~67.3

(1)Includes ~~$3.2~~payments of approximately $21 million ~~paid~~ related to ~~outstanding~~ litigation on the construction of the Bear Den II cryogenic processing plant.

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

~~Table~~Acquisition. In February 2022, we acquired Oasis Midstream, which included cash consideration of ~~Contents~~$160 million, net of cash acquired of approximately $14.9 million.

Investments in Unconsolidated Affiliates. ~~During the six months ended June 30, 2022 and 2021, we contributed approximately $6.5 million and $6.9 million~~Pursuant to our ~~Tres Holdings~~joint venture agreements with our respective equity ~~investment primarily~~investments, we periodically make contributions to our equity investments to fund their expansion projects and for ~~its~~other operating purposes. During the ~~six~~three months ended ~~June 30,~~March 31, 2023 and 2022, ~~and 2021,~~ we contributed approximately ~~$8.5~~$5.1 million and ~~$3.3~~$14.5 million to our ~~Crestwood Permian~~ equity ~~investment primarily to fund its expansion projects.~~investments.

Financing Activities

The following equity and debt transactions impacted our financing activities during the ~~six~~three months ended ~~June 30,~~March 31, 2023 compared to the same period in 2022:

~~Equity and Debt Transactions~~

•During the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, distributions to our partners increased by approximately ~~$39.4~~$8 million compared to the same period in ~~2021,~~2022, primarily due to an increase in common units outstanding as a result of the units issued in conjunction with ~~the merger with Oasis Midstream~~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;

•During the three months ended March 31, 2023, we received approximately $592.5 million from the issuance of the 2031 Senior Notes;

•During the ~~six~~three months ended June 30, 2022, our taxes paid for unit-based compensation vesting increased by approximately $7.4 million compared to the same period in 2021, primarily due to higher vesting of unit-based compensation awards;

•~~During the six months ended June 30,~~March 31, 2022, we borrowed amounts under ~~our revolving~~the Crestwood Midstream credit facility to (i) fund ~~the~~ $160.0 million of cash consideration paid ~~to Oasis Petroleum~~ in conjunction with the merger with Oasis ~~Midstream~~Midstream; and (ii) to repay approximately $218.4 million outstanding under the ~~Oasis Midstream~~ credit facility ~~assumed~~acquired in conjunction with the ~~merger;~~

merger with Oasis Midstream; and

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

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

•~~During the six months ended June 30, 2022,~~March 31, 2023, our other debt-related transactions resulted in net ~~borrowings~~repayments under our credit facilities of ~~$17.3~~approximately $657.1 million compared to net ~~borrowings~~repayments of ~~$127.2~~approximately $100.0 million during the same period in ~~2021.~~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, ~~Crestwood Pipeline and Storage Northeast LLC,~~ Powder River Basin Industrial Complex LLC, and Tres Palacios Holdings LLC and their respective subsidiaries (collectively, Non-Guarantor Subsidiaries). The assets and credit of our Non-Guarantor Subsidiaries are not available to satisfy the debts of the Issuers or Guarantor Subsidiaries, and the liabilities of our Non-Guarantor Subsidiaries do not constitute obligations of the Issuers or Guarantor Subsidiaries. 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 ~~our~~the Crestwood Midstream credit facility and senior notes and related guarantees, see our ~~2021~~2022 Annual Report on Form ~~10-K and Item 1. Financial Statements, Note 8 of this Quarterly Report on Form 10-Q.~~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.

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Summarized Combined Balance Sheet Information (in millions)


		June 30, 2022		December 31, 2021			March 31, 2023		December 31, 2022
Current assets	Current assets	$	835.2	$	574.3	Current assets	$	483.9	$	588.4
Current assets - affiliates	Current assets - affiliates	$	71.2	$	8.4	Current assets - affiliates	$	1.4	$	1.3
Property, plant and equipment, net	Property, plant and equipment, net	$	3,058.5	$	2,161.5	Property, plant and equipment, net	$	3,806.6	$	3,295.8
Non-current assets	Non-current assets	$	1,121.7	$	642.3	Non-current assets	$	1,004.5	$	1,012.9
Current liabilities	Current liabilities	$	602.8	$	578.9	Current liabilities	$	450.5	$	466.1
Current liabilities - affiliates	Current liabilities - affiliates	$	37.0	$	14.7	Current liabilities - affiliates	$	3.4	$	41.5
Long-term debt, less current portion	Long-term debt, less current portion	$	2,929.3	$	2,052.1	Long-term debt, less current portion	$	3,314.5	$	3,171.5
Non-current liabilities	Non-current liabilities	$	139.5	$	138.7	Non-current liabilities	$	195.8	$	147.6

Summarized Combined Statement of Operations Information (in millions)


	~~Six~~Three Months Ended ~~June 30, 2022~~March 31, 2023
Revenues	$	~~2,762.6~~1,242.8
Revenues - affiliates	$	~~231.9~~0.6
Cost of products/services sold	$	~~2,371.8~~992.3
Cost of products/services sold - affiliates	$	~~181.6~~5.5
Operations and maintenance expenses(1)	$	~~78.3~~51.2
General and administrative expenses(2)	$	~~66.7~~30.2
Operating income	$	~~100.5~~97.8
Net income	$	~~24.1~~41.8

(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 ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, we charged ~~$14.8~~$5.0 million to our affiliates under these agreements.

(2) Includes ~~$15.0~~$8.9 million of net general and administrative expenses that were charged by our affiliates to us.

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Item 3.Quantitative and Qualitative Disclosures About Market Risk

Our interest rate risk and commodity price, market and credit risks are discussed in our ~~2021~~2022 Annual Report on Form 10-K. There have been no material changes in those exposures from December 31, ~~2021~~2022 to ~~June 30, 2022.~~March 31, 2023.

Item 4.Controls and Procedures

Disclosure Controls and Procedures

As of ~~June 30, 2022,~~March 31, 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, dodoes 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 ~~June 30, 2022.~~March 31, 2023.

Changes in Internal Control over Financial Reporting

~~On February 1, 2022, we completed the merger with Oasis Midstream and~~There have extended our controls and procedures surrounding our internal control processes that support our internal control over financial reporting to include Oasis Midstream’s operations. Except for this matter, there werebeen no changes toin Crestwood Equity’s or Crestwood Midstream’s internal control over financial reporting during the three ~~and six~~ months ended ~~June 30, 2022~~March 31, 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 ~~2021~~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

None.

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Item 6.Exhibits


Exhibit Number						Description
2.1						Purchase and Sale Agreement, dated as of May 31, 2021 among Con Edison Gas Pipeline and Storage Northeast, LLC, Crestwood Pipeline and Storage Northeast LLC, as the Sellers, Stagecoach Gas Services LLC as the Company, Kinder Morgan Operating LLC “A” as Buyer, Con Edison Transmission, Inc. (solely for the limited purposes set forth therein) and Crestwood Midstream Partners LP (solely for the limited purposes set forth therein) (incorporated by reference to Exhibit 2.1 to Crestwood Equity Partners LP’s Form 8-K filed on June 1, 2021)

2.2						Equity Purchase Agreement, dated as of May 25, 2022, by and among Sendero Midstream Partners, LP, Energy Capital Partners III, LP, Energy Capital Partners III-A, LP, Energy Capital Partners III-B (Sendero IP), LP, Energy Capital Partners III-C (Sendero IP), LP, Carlsbad Co-Invest, LP, ECP III (Sendero Co-Invest) Corp, Sendero Midstream Management, LLC, Sendero Midstream GP, LLC, Crestwood Midstream Partners LP, Crestwood Sendero GP LLC, and Crestwood Equity Partners LP (solely for the limited purposes set forth therein) (incorporated by reference to Exhibit 2.1 to Crestwood Equity Partners LP’s Form 8-K filed on May 26, 2022)

2.3						Contribution Agreement, dated as of May 25, 2022, by and between FR XIII Crestwood Permian Basin Holdings LLC and Crestwood Equity Partners LP (incorporated by reference to Exhibit 2.2 to Crestwood Equity Partners LP’s Form 8-K filed on May 26, 2022)

3.1						Certificate of Limited Partnership of Inergy, L.P. (incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Registration Statement on Form S-1 filed on March 14, 2001)

3.2						Certificate of Correction of Certificate of Limited Partnership of Inergy, L.P. (incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Form 10-Q filed on May 12, 2003)

3.3						Amendment to the Certificate of Limited Partnership of Crestwood Equity Partners LP (the “Company”) (f/k/a Inergy, L.P.) dated as of October 7, 2013 (incorporated herein by reference to Exhibit 3.2 to Crestwood Equity Partners LP's Form 8-K filed on October 10, 2013)

3.4						Certificate of Formation of Inergy GP, LLC (incorporated by reference to Exhibit 3.5 to Inergy, L.P.'s Registration Statement on Form S-1/A filed on May 7, 2001)

3.5						Certificate of Amendment of Crestwood Equity GP LLC (the “General Partner”) (f/k/a Inergy GP, LLC) dated as of October 7, 2013 (incorporated by reference to Exhibit 3.3A to Crestwood Equity Partners LP's Form 10-Q filed on November 8, 2013)

3.6						First Amended and Restated Limited Liability Company Agreement of Inergy GP, LLC dated as of September 27, 2012 (incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Form 8-K filed on September 27, 2012)

3.7						Amendment No. 1 to the First Amended and Restated Limited Liability Company Agreement of the General Partner entered into and effective as of October 7, 2013 (incorporated by reference to Exhibit 3.4A to Crestwood Equity Partners LP's Form 10-Q filed on November 8, 2013)

3.8						Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP dated as of April 11, 2014 (incorporated herein by reference to Exhibit 3.1 to Crestwood Equity Partners LP's Form 8-K filed on April 11, 2014)

3.9						First Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of September 30, 2015 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partner LP’s Form 8-K filed on October 1, 2015)

3.10						Second Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of November 8, 2017 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partners LP’s Form 8-K filed on November 13, 2017)

3.11						Third Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of May 30, 2018 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partners LP’s Form 8-K filed on June 4, 2018)

3.12						Second Amended and Restated Agreement of Limited Partnership of Crestwood Midstream Partners LP, dated as of September 30, 2015 (incorporated by reference to Exhibit 3.1 to Crestwood Midstream Partners LP's Form 8-K filed on October 1, 2015)

3.13						Certificate of Formation of NRGM GP, LLC (incorporated herein by reference to Exhibit 3.7 to Inergy Midstream, L.P.'s Form S-1/A filed on November 21, 2011)

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3.14						Amended and Restated Limited Liability Company Agreement of NRGM GP, LLC, dated December 21, 2011 (incorporated herein by reference to Exhibit 3.2 to Inergy Midstream, L.P.'s Form 8-K filed on December 22, 2011)

3.15						Amendment No. 1 to the Amended and Restated Limited Liability Company Agreement of Crestwood Midstream GP LLC (f/k/a NRGM GP, LLC) (incorporated herein by reference to Exhibit 3.39 to Crestwood Midstream Partners LP's Form S-4/A filed on October 28, 2013)

3.16						Fourth Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of June 28, 2019 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partners LP’s Form 8-K filed on June 28, 2019)

3.17						Sixth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP dated August 20, 2021 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partners LP’s Form 8-K filed on August 20, 2021)

3.18						Second Amended and Restated Limited Liability Company Agreement of Crestwood Equity GP LLC dated August 20, 2021 (incorporated by reference to Exhibit 3.2 to Crestwood Equity Partners LP’s Form 8-K on August 20, 2021)

*4.1						Indenture, dated as of January 19, 2023, among Crestwood Midstream Partners LP, Crestwood Midstream Finance Corp., the guarantors names therein and U.S. Bank Trust Company, National Association, as trustee (incorporated by reference to Exhibit 4.1 to Crestwood Equity Partners LP’s For m 8-K on January 19, 2023)

4.2						Form of 7.375% Senior Note due 2031 (included in Exhibit 4.1)

*4.3						Sixth Supplemental Indenture, dated as of ~~July 1, 2022,~~February 13, 2023, among Crestwood Midstream Partners LP, Crestwood Midstream Finance Corp., the guarantors named therein and U.S. Bank Trust Company, National Association, as ~~successor in interest to U.S. Bank National Association, as trustee~~trustee.

*~~4.2~~4.4						Third Supplemental Indenture, dated as of ~~July 1, 2022, among Crestwood Midstream Partners LP, Crestwood Midstream Finance Corp., the guarantors named therein and Regions Bank as trustee~~

*4.3						~~Fifth Supplemental Indenture, dated as of July 20, 2022,~~February 13, 2023, among Crestwood Midstream Partners LP, Crestwood Midstream Finance Corp., the guarantors named therein and U.S. Bank Trust Company, National Association, as ~~successor in interest to U.S. Bank National Association, as trustee~~trustee.

*~~4.4~~4.5						~~Second~~Third Supplemental Indenture, dated as of ~~July 20, 2022,~~February 13, 2023, among Crestwood Midstream Partners LP, Crestwood Midstream Finance Corp., the guarantors named therein and U.S. Bank Trust Company, National Association, as ~~successor in interest to U.S. Bank National Association, as trustee~~trustee.

*~~4.5~~4.6						~~Second~~ Third Supplemental Indenture, dated February 13, 2023, among Crestwood Midstream Partners LP, Crestwood Midstream Finance Corp., the guarantors named therein and Regions Bank, as trustee.

*4.7						Supplemental Indenture, dated as of ~~July 20, 2022,~~February 13, 2023, among Crestwood Midstream Partners LP, Crestwood Midstream Finance Corp., the guarantors named therein and U.S. Bank Trust Company, National Association, as ~~successor in interest to U.S. Bank National Association, as trustee~~

*4.6						~~Second Supplemental Indenture, dated as of July 20, 2022, among Crestwood Midstream Partners LP, Crestwood Midstream Finance Corp., the guarantors named therein and Regions Bank, as trustee~~

~~10.1~~						Registration Rights Agreement, dated July 11, 2022, by and between Crestwood Equity Partners LP and FR XIII Crestwood Permian Basin Holdings LLC (incorporated by reference to Exhibit 10.1 to Crestwood Equity Partners LP’s Form 8-K filed on July 15, 2022)

~~10.2~~						Director Nomination and Voting Support Agreement, dated July 11, 2022, by and among Crestwood Equity Partners LP, Crestwood Equity GP LLC, and FR XIII Crestwood Permian Basin Holdings LLC (incorporated by reference to Exhibit 10.2 to Crestwood Equity Partners LP’s Form 8-K filed on July 15, 2022)

~~10.3~~						First Amendment to Amended and Restated Credit Agreement, dated as of April 13, 2022, by and among CPB Subsidiary Holdings LLC, Crestwood Permian Basin Holdings LLC, Wells Fargo Bank, National Association, the institutions set forth on Schedule 1 thereto and the other Lenders party thereto (incorporated by reference to Exhibit 10.3 to Crestwood Equity Partners LP’s Form 8-K filed on July 15, 2022)trustee.

*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

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*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

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**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.

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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:

~~July 28, 2022~~May 4, 2023

By:

/s/ ~~ROBERT T. HALPIN~~JOHN BLACK

~~Robert T. Halpin~~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:

~~July 28, 2022~~May 4, 2023

By:

/s/ ~~ROBERT T. HALPIN~~JOHN BLACK

~~Robert T. Halpin~~John Black

Executive Vice President and Chief Financial Officer

(Duly Authorized Officer and Principal Financial Officer)

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


	Three Months Ended June 30,		Six Months Ended June 30,
	2021		2022		2021
Revenues	$	1,024.9	$	3,066.4	$	2,157.9
Net income (loss)	$	(15.5)	$	67.8	$	(31.1)
Net income (loss) per limited partner unit:
Basic	$	(0.42)	$	0.18	$	(0.80)
Diluted	$	(0.42)	$	0.17	$	(0.80)


	Distributions(1)				Contributions
	Six Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2021		2022		2021
Crestwood Permian	$	13.6	$	5.5	$	8.5	$	3.3
Tres Holdings	1.4		10.6		6.5		6.9
PRBIC	—		0.1		—		—
Stagecoach Gas	—		27.0		—		—
Total	$	15.0	$	43.2	$	15.0	$	10.2


	June 30, 2022		December 31, 2021
Aggregate fair value liability of derivative instruments with credit-risk-related contingent features(1)	$	53.9	$	57.9
Broker-related net derivative asset position	$	67.4	$	104.8
Broker-related cash collateral received	$	45.6	$	76.8
Cash collateral (paid) received, net	$	(2.8)	$	11.4


	Three Months Ended June 30, 2021
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	148.6	$	24.7	$	756.3	$	—	$	929.6
Intersegment revenues	84.2		—		(84.2)		—		—
Costs of product/services sold	120.5		0.1		676.6		—		797.2
Operations and maintenance expense	9.0		5.7		11.1		—		25.8
General and administrative expense	—		—		—		19.7		19.7

Gain on long-lived assets, net	0.3		—		—		—		0.3
Earnings (loss) from unconsolidated affiliates, net	—		1.0		(28.1)		—		(27.1)
Crestwood Midstream EBITDA	$	103.6	$	19.9	$	(43.7)	$	(19.7)	$	60.1
Crestwood Equity
General and administrative expense	—		—		—		3.1		3.1
Other income, net	—		—		—		0.1		0.1
Crestwood Equity EBITDA	$	103.6	$	19.9	$	(43.7)	$	(22.7)	$	57.1


	Six Months Ended June 30, 2022
	Gathering and Processing North		Gathering and Processing South		Storage and Logistics		Corporate		Total
Crestwood Midstream
Revenues	$	514.6	$	66.0	$	2,451.2	$	—	$	3,031.8
Intersegment revenues	279.0		—		(279.0)		—		—
Costs of product/services sold	456.4		—		2,121.2		—		2,577.6
Operations and maintenance expense	51.2		14.3		23.5		—		89.0
General and administrative expense	—		—		—		66.7		66.7
Loss on long-lived assets, net	—		(60.2)		(4.1)		—		(64.3)

Earnings from unconsolidated affiliates, net	—		7.4		1.6		—		9.0
Crestwood Midstream EBITDA	$	286.0	$	(1.1)	$	25.0	$	(66.7)	$	243.2
Crestwood Equity
General and administrative expense	—		—		—		3.2		3.2
Elimination of loss on long-lived assets(1)	—		53.3		—		—		53.3
Other income, net	—		—		—		0.2		0.2
Crestwood Equity EBITDA	$	286.0	$	52.2	$	25.0	$	(69.7)	$	293.5