10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

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

For the quarterly period ended June 30, 2020

OR

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

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

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

(832) 519-2200

(Registrant’s telephone number, including area code)

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

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

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

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

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).

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

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

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

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

Crestwood Equity Partners LP	☐
Crestwood Midstream Partners LP	☐

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

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

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date (July 31, 2020).

Crestwood Equity Partners LP	73,161,478
Crestwood Midstream Partners LP	None

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

CRESTWOOD EQUITY PARTNERS LP

CRESTWOOD MIDSTREAM PARTNERS LP

INDEX TO FORM 10-Q

	Page
Part I – Financial Information
Item 1. Financial Statements (Unaudited):
Crestwood Equity Partners LP
Consolidated Balance Sheets	4
Consolidated Statements of Operations	5
Consolidated Statements of Comprehensive Income	7
Consolidated Statements of Partners’ Capital	8
Consolidated Statements of Cash Flows	10
Crestwood Midstream Partners LP
Consolidated Balance Sheets	11
Consolidated Statements of Operations	12
Consolidated Statements of Partners’ Capital	13
Consolidated Statements of Cash Flows	14
Notes to Consolidated Financial Statements	15
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	48
Item 3. Quantitative and Qualitative Disclosures About Market Risk	62
Item 4. Controls and Procedures	62
Part II – Other Information
Item 1. Legal Proceedings	63
Item 1A. Risk Factors	63
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	66
Item 3. Defaults Upon Senior Securities	66
Item 4. Mine Safety Disclosures	66
Item 5. Other Information	66
Item 6. Exhibits	67
Signature	69

3

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED BALANCE SHEETS (in millions, except unit information)
	June 30, 2020		December 31, 2019
	(unaudited)
Assets
Current assets:
Cash	$	6.7	$	25.7
Accounts receivable, less allowance for doubtful accounts of $0.6 million and $0.3 million at June 30, 2020 and December 31, 2019	165.9		242.2
Inventory	88.9		53.7
Assets from price risk management activities	44.4		43.2
Prepaid expenses and other current assets	8.7		11.6
Total current assets	314.6		376.4
Property, plant and equipment	3,829.2		3,612.5
Less: accumulated depreciation	786.8		703.4
Property, plant and equipment, net	3,042.4		2,909.1
Intangible assets	1,118.1		1,076.3
Less: accumulated amortization	301.0		271.1
Intangible assets, net	817.1		805.2
Goodwill	138.6		218.9
Operating lease right-of-use assets, net	44.2		53.8
Investments in unconsolidated affiliates	961.9		980.4
Other non-current assets	4.9		5.5
Total assets	$	5,323.7	$	5,349.3
Liabilities and capital
Current liabilities:
Accounts payable	$	118.6	$	189.2
Accrued expenses and other liabilities	133.8		161.7
Liabilities from price risk management activities	32.2		6.7
Current portion of long-term debt	0.2		0.2
Total current liabilities	284.8		357.8
Long-term debt, less current portion	2,575.7		2,328.3
Other long-term liabilities	285.7		301.6
Deferred income taxes	2.3		2.6
Total liabilities	3,148.5		2,990.3
Commitments and contingencies (Note 11)
Interest of non-controlling partner in subsidiary (Note 10)	430.6		426.2
Crestwood Equity Partners LP partners’ capital (73,605,008 and 72,282,942 common and subordinated units issued and outstanding at June 30, 2020 and December 31, 2019)	1,132.6		1,320.8
Preferred units (71,257,445 units issued and outstanding at both June 30, 2020 and December 31, 2019)	612.0		612.0
Total partners’ capital	1,744.6		1,932.8
Total liabilities and capital	$	5,323.7	$	5,349.3

See accompanying notes.

4

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF OPERATIONS (in millions, except per unit data) (unaudited)
	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2020		2019			2020		2019
Revenues:
Product revenues:
Gathering and processing	$	30.5	$	106.2		$	133.2	$	215.8
Marketing, supply and logistics	220.5		472.1			717.0		1,108.9
Related party (Note 12)	7.4		1.3			14.7		2.5
	258.4		579.6			864.9		1,327.2
Services revenues:
Gathering and processing	84.0		93.5			196.2		166.2
Storage and transportation	3.1		4.9			6.6		12.7
Marketing, supply and logistics	7.1		5.4			12.6		12.5
Related party (Note 12)	0.1		—			0.3		—
	94.3		103.8			215.7		191.4
Total revenues	352.7		683.4			1,080.6		1,518.6
Costs of product/services sold (exclusive of items shown separately below):
Product costs	217.4		529.5			742.0		1,183.0
Product costs - related party (Note 12)	3.6		0.9			6.8		35.3
Service costs	4.7		6.8			11.3		14.5
Total costs of products/services sold	225.7		537.2			760.1		1,232.8
Operating expenses and other:
Operations and maintenance	31.6		34.7			69.2		63.3
General and administrative	29.5		22.3			44.4		59.5
Depreciation, amortization and accretion	61.0		49.3			117.1		89.1
Loss on long-lived assets, net	3.8		—			4.8		2.0
Goodwill impairment	—		—			80.3		—
Gain on acquisition	—		(209.4		)	—		(209.4		)
	125.9		(103.1		)	315.8		4.5
Operating income	1.1		249.3			4.7		281.3

5

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF OPERATIONS (continued) (in millions, except per unit data) (unaudited)
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2020			2019			2020			2019
Earnings from unconsolidated affiliates, net	8.4			3.7			13.9			10.6
Interest and debt expense, net	(34.0		)	(27.8		)	(66.6		)	(52.7		)
Other income, net	0.1			0.1			0.2			0.2
Income (loss) before income taxes	(24.4		)	225.3			(47.8		)	239.4
(Provision) benefit for income taxes	0.1			(0.3		)	0.1			(0.3		)
Net income (loss)	(24.3		)	225.0			(47.7		)	239.1
Net income attributable to non-controlling partner	10.2			10.6			20.1			14.6
Net income (loss) attributable to Crestwood Equity Partners LP	(34.5		)	214.4			(67.8		)	224.5
Net income attributable to preferred units	15.0			15.0			30.0			30.0
Net income (loss) attributable to partners	$	(49.5	)	$	199.4		$	(97.8	)	$	194.5
Subordinated unitholders’ interest in net income	$	—		$	1.2		$	—		$	1.2
Common unitholders’ interest in net income (loss)	$	(49.5	)	$	198.2		$	(97.8	)	$	193.3
Net income (loss) per limited partner unit:
Basic	$	(0.68	)	$	2.76		$	(1.34	)	$	2.69
Diluted	$	(0.68	)	$	2.58		$	(1.34	)	$	2.53
Weighted-average limited partners’ units outstanding:
Basic	73.2			71.8			73.0			71.8
Dilutive	—			11.2			—			5.2
Diluted	73.2			83.0			73.0			77.0

See accompanying notes.

6

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (in millions) (unaudited)
	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2020			2019		2020			2019
Net income (loss)	$	(24.3	)	$	225.0	$	(47.7	)	$	239.1
Change in fair value of Suburban Propane Partners, L.P. units	—			0.3		(1.1		)	0.7
Comprehensive income (loss)	(24.3		)	225.3		(48.8		)	239.8
Comprehensive income attributable to non-controlling partner	10.2			10.6		20.1			14.6
Comprehensive income (loss) attributable to Crestwood Equity Partners LP	$	(34.5	)	$	214.7	$	(68.9	)	$	225.2

See accompanying notes.

7

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL (in millions) (unaudited)
	Preferred				Partners
	Units	Capital			Common Units		Subordinated Units	Capital			Total Partners’ Capital
Balance at December 31, 2019	71.3	$	612.0		71.9		0.4	$	1,320.8		$	1,932.8
Distributions to partners	—	(15.0		)	—		—	(45.3		)	(60.3		)
Unit-based compensation charges	—	—			1.7		—	0.2			0.2
Taxes paid for unit-based compensation vesting	—	—			(0.5	)	—	(15.1		)	(15.1		)
Change in fair value of Suburban Propane Partners, L.P. units	—	—			—		—	(1.1		)	(1.1		)
Other	—	—			0.2		—	3.5			3.5
Net income (loss)	—	15.0			—		—	(48.3		)	(33.3		)
Balance at March 31, 2020	71.3	612.0			73.3		0.4	1,214.7			1,826.7
Distributions to partners	—	(15.0		)	—		—	(45.7		)	(60.7		)
Unit-based compensation charges	—	—			—		—	13.6			13.6
Taxes paid for unit-based compensation vesting	—	—			(0.1	)	—	(0.4		)	(0.4		)
Other	—	—			—		—	(0.1		)	(0.1		)
Net income (loss)	—	15.0			—		—	(49.5		)	(34.5		)
Balance at June 30, 2020	71.3	$	612.0		73.2		0.4	$	1,132.6		$	1,744.6

8

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL (continued) (in millions) (unaudited)
	Preferred				Partners
	Units	Capital			Common Units		Subordinated Units	Capital			Non-Controlling Partner			Total Partners’ Capital
Balance at December 31, 2018	71.3	$	612.0		71.2		0.4	$	1,240.5		$	181.3		$	2,033.8
Distributions to partners	—	(15.0		)	—		—	(43.1		)	(3.3		)	(61.4		)
Unit-based compensation charges	—	—			0.9		—	17.3			—			17.3
Taxes paid for unit-based compensation vesting	—	—			(0.2	)	—	(7.0		)	—			(7.0		)
Change in fair value of Suburban Propane Partners, L.P. units	—	—			—		—	0.4			—			0.4
Other	—	—			—		—	(0.7		)	—			(0.7		)
Net income (loss)	—	15.0			—		—	(4.9		)	4.0			14.1
Balance at March 31, 2019	71.3	612.0			71.9		0.4	1,202.5			182.0			1,996.5
Distributions to partners	—	(15.0		)	—		—	(43.1		)	(3.3		)	(61.4		)
Unit-based compensation charges	—	—			—		—	11.3			—			11.3
Taxes paid for unit-based compensation vesting	—	—			(0.1	)	—	(3.6		)	—			(3.6		)
Change in fair value of Suburban Propane Partners, L.P. units	—	—			—		—	0.3			—			0.3
Non-controlling interest reclassification (Note 10)	—	—			—		—	—			(178.8		)	(178.8		)
Other	—	—			—		—	(0.4		)	0.1			(0.3		)
Net income	—	15.0			—		—	199.4			—			214.4
Balance at June 30, 2019	71.3	$	612.0		71.8		0.4	$	1,366.4		$	—		$	1,978.4

See accompanying notes.

9

CRESTWOOD EQUITY PARTNERS LP CONSOLIDATED STATEMENTS OF CASH FLOWS (in millions) (unaudited)
	Six Months Ended
	June 30,
	2020			2019
Operating activities
Net income (loss)	$	(47.7	)	$	239.1
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	117.1			89.1
Amortization of debt-related deferred costs	3.2			2.9
Unit-based compensation charges	9.2			28.6
Loss on long-lived assets, net	4.8			2.0
Gain on acquisition	—			(209.4		)
Goodwill impairment	80.3			—
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	5.4			6.3
Deferred income taxes	(0.3		)	0.3
Changes in operating assets and liabilities	11.4			35.0
Net cash provided by operating activities	183.4			193.9
Investing activities
Acquisitions, net of cash acquired (Note 3)	(162.3		)	(462.1		)
Purchases of property, plant and equipment	(143.2		)	(204.7		)
Investments in unconsolidated affiliates	(6.0		)	(40.9		)
Capital distributions from unconsolidated affiliates	18.9			24.2
Other	(0.3		)	(0.5		)
Net cash used in investing activities	(292.9		)	(684.0		)
Financing activities
Proceeds from the issuance of long-term debt	742.5			1,544.0
Payments on long-term debt	(498.2		)	(1,159.5		)
Payments on finance leases	(1.6		)	(1.9		)
Payments for deferred financing costs	—			(9.0		)
Net proceeds from issuance of non-controlling interest	2.8			235.0
Distributions to partners	(91.0		)	(86.2		)
Distributions to non-controlling partner	(18.5		)	(6.6		)
Distributions to preferred unitholders	(30.0		)	(30.0		)
Taxes paid for unit-based compensation vesting	(15.5		)	(10.6		)
Other	—			(0.2		)
Net cash provided by financing activities	90.5			475.0
Net change in cash	(19.0		)	(15.1		)
Cash at beginning of period	25.7			17.2
Cash at end of period	$	6.7		$	2.1
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$	35.9		$	(22.2	)

See accompanying notes.

10

CRESTWOOD MIDSTREAM PARTNERS LP CONSOLIDATED BALANCE SHEETS (in millions)
	June 30, 2020		December 31, 2019
	(unaudited)
Assets
Current assets:
Cash	$	6.1	$	25.4
Accounts receivable, less allowance for doubtful accounts of $0.6 million and $0.3 million at June 30, 2020 and December 31, 2019	165.8		241.9
Inventory	88.9		53.7
Assets from price risk management activities	44.4		43.2
Prepaid expenses and other current assets	8.7		11.6
Total current assets	313.9		375.8
Property, plant and equipment	4,159.2		3,942.6
Less: accumulated depreciation	965.5		875.1
Property, plant and equipment, net	3,193.7		3,067.5
Intangible assets	1,118.1		1,076.3
Less: accumulated amortization	301.0		271.1
Intangible assets, net	817.1		805.2
Goodwill	138.6		218.9
Operating lease right-of-use assets, net	44.2		53.8
Investments in unconsolidated affiliates	961.9		980.4
Other non-current assets	2.9		2.4
Total assets	$	5,472.3	$	5,504.0
Liabilities and capital
Current liabilities:
Accounts payable	$	116.1	$	186.6
Accrued expenses and other liabilities	132.4		160.4
Liabilities from price risk management activities	32.2		6.7
Current portion of long-term debt	0.2		0.2
Total current liabilities	280.9		353.9
Long-term debt, less current portion	2,575.7		2,328.3
Other long-term liabilities	284.0		295.6
Deferred income taxes	0.6		0.7
Total liabilities	3,141.2		2,978.5
Commitments and contingencies (Note 11)
Interest of non-controlling partner in subsidiary (Note 10)	430.6		426.2
Partners’ capital	1,900.5		2,099.3
Total liabilities and capital	$	5,472.3	$	5,504.0

See accompanying notes.

11

CRESTWOOD MIDSTREAM PARTNERS LP CONSOLIDATED STATEMENTS OF OPERATIONS (in millions) (unaudited)
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2020			2019			2020			2019
Revenues:
Product revenues:
Gathering and processing	$	30.5		$	106.2		$	133.2		$	215.8
Marketing, supply and logistics	220.5			472.1			717.0			1,108.9
Related party (Note 12)	7.4			1.3			14.7			2.5
	258.4			579.6			864.9			1,327.2
Service revenues:
Gathering and processing	84.0			93.5			196.2			166.2
Storage and transportation	3.1			4.9			6.6			12.7
Marketing, supply and logistics	7.1			5.4			12.6			12.5
Related party (Note 12)	0.1			—			0.3			—
	94.3			103.8			215.7			191.4
Total revenues	352.7			683.4			1,080.6			1,518.6
Costs of product/services sold (exclusive of items shown separately below):
Product costs	217.4			529.5			742.0			1,183.0
Product costs - related party (Note 12)	3.6			0.9			6.8			35.3
Service costs	4.7			6.8			11.3			14.5
Total costs of product/services sold	225.7			537.2			760.1			1,232.8
Operating expenses and other:
Operations and maintenance	31.6			34.7			69.2			63.3
General and administrative	28.4			20.9			41.9			56.9
Depreciation, amortization and accretion	64.6			52.7			124.2			96.1
Loss on long-lived assets, net	3.8			—			4.8			2.0
Goodwill impairment	—			—			80.3			—
Gain on acquisition	—			(209.4		)	—			(209.4		)
	128.4			(101.1		)	320.4			8.9
Operating income (loss)	(1.4		)	247.3			0.1			276.9
Earnings from unconsolidated affiliates, net	8.4			3.7			13.9			10.6
Interest and debt expense, net	(34.0		)	(27.8		)	(66.6		)	(52.7		)
Income (loss) before income taxes	(27.0		)	223.2			(52.6		)	234.8
(Provision) benefit for income taxes	0.2			(0.3		)	0.2			(0.3		)
Net income (loss)	(26.8		)	222.9			(52.4		)	234.5
Net income attributable to non-controlling partner	10.2			10.6			20.1			14.6
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(37.0	)	$	212.3		$	(72.5	)	$	219.9

See accompanying notes.

12

CRESTWOOD MIDSTREAM PARTNERS LP CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL (in millions) (unaudited)
	Total Partners’ Capital
Balance at December 31, 2019	$	2,099.3
Distributions to partners	(57.0		)
Unit-based compensation charges	(4.4		)
Taxes paid for unit-based compensation vesting	(15.1		)
Other	(1.1		)
Net loss	(35.5		)
Balance at March 31, 2020	1,986.2
Distributions to partners	(62.0		)
Unit-based compensation charges	13.6
Taxes paid for unit-based compensation vesting	(0.4		)
Other	0.1
Net loss	(37.0		)
Balance at June 30, 2020	$	1,900.5

	Partners			Non-Controlling Partner			Total Partners’ Capital
Balance at December 31, 2018	$	2,028.2		$	181.3		$	2,209.5
Distributions to partners	(57.8		)	(3.3		)	(61.1		)
Unit-based compensation charges	17.3			—			17.3
Taxes paid for unit-based compensation vesting	(7.0		)	—			(7.0		)
Other	(0.3		)	—			(0.3		)
Net income	7.6			4.0			11.6
Balance at March 31, 2019	1,988.0			182.0			2,170.0
Distributions to partners	(59.7		)	(3.3		)	(63.0		)
Unit-based compensation charges	11.3			—			11.3
Taxes paid for unit-based compensation vesting	(3.6		)	—			(3.6		)
Non-controlling interest reclassification (Note 10)	—			(178.8		)	(178.8		)
Other	(0.1		)	0.1			—
Net income	212.3			—			212.3
Balance at June 30, 2019	$	2,148.2		$	—		$	2,148.2

See accompanying notes.

13

CRESTWOOD MIDSTREAM PARTNERS LP CONSOLIDATED STATEMENTS OF CASH FLOWS (in millions) (unaudited)
	Six Months Ended
	June 30,
	2020			2019
Operating activities
Net income (loss)	$	(52.4	)	$	234.5
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	124.2			96.1
Amortization of debt-related deferred costs	3.2			2.9
Unit-based compensation charges	9.2			28.6
Loss on long-lived assets, net	4.8			2.0
Goodwill impairment	80.3			—
Gain on acquisition	—			(209.4		)
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	5.4			6.3
Deferred income taxes	(0.1		)	0.2
Changes in operating assets and liabilities	6.5			33.9
Net cash provided by operating activities	181.1			195.1
Investing activities
Acquisitions, net of cash acquired (Note 3)	(162.3		)	(462.1		)
Purchases of property, plant and equipment	(143.2		)	(204.7		)
Investments in unconsolidated affiliates	(6.0		)	(40.9		)
Capital distributions from unconsolidated affiliates	18.9			24.2
Other	(0.3		)	(0.5		)
Net cash used in investing activities	(292.9		)	(684.0		)
Financing activities
Proceeds from the issuance of long-term debt	742.5			1,544.0
Payments on long-term debt	(498.2		)	(1,159.5		)
Payments on finance leases	(1.6		)	(1.9		)
Payments for deferred financing costs	—			(9.0		)
Net proceeds from issuance of non-controlling interest	2.8			235.0
Distributions to partners	(119.0		)	(117.5		)
Distributions to non-controlling partner	(18.5		)	(6.6		)
Taxes paid for unit-based compensation vesting	(15.5		)	(10.6		)
Net cash provided by financing activities	92.5			473.9
Net change in cash	(19.3		)	(15.0		)
Cash at beginning of period	25.4			16.5
Cash at end of period	$	6.1		$	1.5
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$	35.9		$	(22.2	)

See accompanying notes.

14

CRESTWOOD EQUITY PARTNERS LP

CRESTWOOD MIDSTREAM PARTNERS LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 1 – Organization and Business Description

Organization

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

The accompanying consolidated financial statements and related notes should be read in conjunction with our 2019 Annual Report on Form 10-K filed with the Securities and Exchange Commission (SEC) on February 21, 2020. The financial information as of June 30, 2020, and for the three and six months ended June 30, 2020 and 2019, is unaudited. The consolidated balance sheets as of December 31, 2019, were derived from the audited balance sheets filed in our 2019 Annual Report on Form 10-K.

Business Description

Crestwood Equity is a publicly-traded Delaware limited partnership that develops, acquires, owns or controls, and operates primarily fee-based assets and operations within the energy midstream sector. We provide broad-ranging infrastructure solutions across the value chain to service premier liquids-rich natural gas and crude oil shale plays across the United States. We own and operate a diversified portfolio of crude oil and natural gas gathering, processing, storage 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, a Delaware limited partnership.

Note 2 – Basis of Presentation and Summary of Significant Accounting Policies

Basis of Presentation

Our consolidated financial statements are prepared in accordance with Generally Accepted Accounting Principles (GAAP) and include the accounts of all consolidated subsidiaries after the elimination of all intercompany accounts and transactions. In management’s opinion, all necessary adjustments to fairly present our results of operations, financial position and cash flows for the periods presented have been made and all such adjustments are of a normal and recurring nature. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.

Significant Accounting Policies

There were no material changes in our significant accounting policies from those described in our 2019 Annual Report on Form 10-K. Below is an update of our accounting policies related to Goodwill and Accounts Receivable.

Goodwill

Our goodwill represents the excess of the amount we paid for a business over the fair value of the net identifiable assets acquired. We evaluate goodwill for impairment annually on December 31, and whenever events indicate that it is more likely than not that the fair value of a reporting unit could be less than its carrying amount. This evaluation requires us to compare the fair value of each of our reporting units to its carrying value (including goodwill). If the fair value exceeds the carrying amount, goodwill of the reporting unit is not considered impaired.

We estimate the fair value of our reporting units based on a number of factors, including discount rates, projected cash flows and the potential value we would receive if we sold the reporting unit. Estimating projected cash flows requires us to make

15

certain assumptions as it relates to the future operating performance of each of our reporting units (which includes assumptions, among others, about estimating future operating margins and related future growth in those margins, contracting efforts and the cost and timing of facility expansions) and assumptions related to our customers, such as their future capital and operating plans and their financial condition. When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. If the assumptions embodied in the projections prove inaccurate, we could incur a future impairment charge. In addition, the use of the income approach to determine the fair value of our reporting units (see further discussion of the use of the income approach below) could result in a different fair value if we had utilized a market approach, or a combination thereof.

The following table summarizes the goodwill of our various reporting units (in millions):

			Impairment during the six months ended
	December 31, 2019		June 30, 2020		June 30, 2020
Gathering and Processing
Arrow	$	45.9	$	—	$	45.9
Powder River Basin	80.3		80.3		—
Marketing, Supply and Logistics
NGL Marketing and Logistics	92.7		—		92.7
Total	$	218.9	$	80.3	$	138.6

During the first quarter of 2020, current and forward commodity prices significantly declined from their levels at December 31, 2019 due primarily to the decreases in energy demand as a result of the outbreak of the COVID-19 pandemic and actions taken by the Organization of the Petroleum Exporting Countries, Russia, the United States and other oil-producing countries relating to the oversupply of oil. We currently anticipate that the decrease in commodity prices will have a negative impact on certain of our customers in our gathering and processing segment, which could adversely impact the financial performance of certain of the reporting units within those operations.

Upon acquisition, we are required to record the assets, liabilities and goodwill of a reporting unit at its fair value on the date of acquisition. As a result, any level of decrease in the forecasted cash flows of these businesses or increases in the discount rates utilized to value those businesses from their respective acquisition dates would likely result in the fair value of the reporting unit falling below the carrying value of the reporting unit, and could result in an assessment of whether that reporting unit's goodwill is impaired.

We acquired our Powder River Basin reporting unit in 2019 and recorded it at fair value at that time. Based on the events that occurred during the first quarter of 2020 described above, we determined that the forecasted cash flows, and therefore the fair value, of our Powder River Basin reporting unit significantly decreased during the first quarter of 2020, and accordingly performed a quantitative impairment assessment of the goodwill related to that reporting unit during that period. Based on our quantitative assessment, which utilized the income approach, we determined that the goodwill associated with the Powder River Basin reporting unit should be fully impaired during the first quarter of 2020, and accordingly recorded an $80.3 million impairment of the goodwill attributed to that reporting unit during the first quarter of 2020. We did not record any impairments of the goodwill associated with our Arrow or NGL Marketing and Logistics reporting units during the six months ended June 30, 2020, as we do not have indicators that it is more likely than not that the fair value of those reporting units has declined to below their carrying value at June 30, 2020.

Accounts Receivable

Effective January 1, 2020, we adopted the provision of Accounting Standards Update 2016-13, Financial Instruments - Credit Losses (Topic 326), which provides revised guidance on evaluating accounts and notes receivable and other financial instruments for impairment. We record accounts receivable when products or services are delivered and it is probable that payment will be received for those products or services, and we do not record any interest or penalties on accounts receivable that are past due under the terms of the related arrangement or invoice until those amounts are received. Topic 326 requires companies to evaluate their financial instruments for impairment by recording an allowance for doubtful accounts and/or bad debt expense based on certain categories of instruments rather than a specific identification approach. We adopted the

16

provisions of this standard using a method to estimate the allowance for doubtful accounts that considered both the aging of our accounts receivable and the projected loss rate of our receivables. We write off accounts receivable, and the related allowance for doubtful accounts, when it becomes remote that payment for products or services will be received. On January 1, 2020, we recorded a $0.7 million increase to our allowance for doubtful accounts and a $0.7 million decrease to partners’ capital to reflect the cumulative effect of adopting the new standard. In addition, on January 1, 2020, Crestwood Permian Basin Holdings LLC (Crestwood Permian), our 50% equity investment, also adopted the provisions of Topic 326 and we recorded a decrease of approximately $0.2 million to our equity investment and a corresponding decrease to our partners’ capital to reflect our proportionate share of the cumulative effect of accounting change recorded by the equity investment related to the new standard. The adoption of this standard was not material to our other equity investments.

Note 3 – Acquisitions

NGL Asset Acquisition

In April 2020, we acquired several NGL storage and rail-to-truck liquid petroleum gas (LPG) terminals from Plains All American Pipeline, L.P. (Plains) for approximately $162 million. The acquired assets include 7 MMBbls of NGL storage and seven LPG terminals, and resulted in an increase of approximately $160 million in our property, plant and equipment and intangible assets and an increase of approximately $2 million to our other assets and liabilities, net during the three months ended June 30, 2020. We allocated the purchase price to these assets and liabilities based on their fair values, which are Level 3 fair value measurements and were developed by management with the assistance of a third-party valuation firm utilizing market-related information about the property, plant and equipment and customer relationships acquired. These assets are included in our marketing, supply and logistics segment. The transaction costs related to this acquisition were not material for the three and six months ended June 30, 2020.

Jackalope Acquisition

On April 9, 2019, Crestwood Niobrara LLC (Crestwood Niobrara), our consolidated subsidiary, acquired Williams Partners LP’s (Williams) 50% equity interest in Jackalope Gas Gathering Services, L.L.C. (Jackalope) for approximately $484.6 million (Jackalope Acquisition). The acquisition was funded through a combination of borrowings under the CMLP credit facility and the issuance of $235 million of new preferred units to CN Jackalope Holdings LLC (Jackalope Holdings) (see Note 10 for a further discussion of the issuance of the new preferred units). Prior to the Jackalope Acquisition, Crestwood Niobrara owned a 50% equity interest in Jackalope, which we accounted for under the equity method of accounting. As a result of this transaction, Crestwood Niobrara controls and owns 100% of the equity interests in Jackalope. The financial results of Jackalope are included in our gathering and processing segment from the date of the acquisition.

The fair value of the assets acquired and liabilities assumed in the Jackalope Acquisition exceeded the sum of the cash consideration paid and the historical book value of our 50% equity interest in Jackalope (which was remeasured at fair value and derecognized) and, as a result, we recognized a gain of approximately $209.4 million. This gain is included in gain on acquisition in our consolidated statements of operations.

17

Note 4 – Certain Balance Sheet Information

Accrued Expenses and Other Liabilities

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

	CEQP				CMLP
	June 30,		December 31,		June 30,		December 31,
	2020		2019		2020		2019
Accrued expenses	$	35.1	$	61.6	$	33.7	$	60.3
Accrued property taxes	8.2		6.1		8.2		6.1
Income tax payable	0.3		0.3		0.3		0.3
Interest payable	25.0		25.6		25.0		25.6
Accrued additions to property, plant and equipment	14.9		38.0		14.9		38.0
Contingent consideration	19.0		—		19.0		—
Operating leases	17.8		18.1		17.8		18.1
Finance leases	3.3		3.2		3.3		3.2
Deferred revenue	10.2		8.8		10.2		8.8
Total accrued expenses and other liabilities	$	133.8	$	161.7	$	132.4	$	160.4

Other Long-Term Liabilities

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

	CEQP				CMLP
	June 30,		December 31,		June 30,		December 31,
	2020		2019		2020		2019
Contract liabilities	$	159.6	$	144.7	$	159.6	$	144.7
Contingent consideration	38.0		57.0		38.0		57.0
Operating leases	32.9		41.5		32.9		41.5
Asset retirement obligations	34.6		33.3		34.6		33.3
Other	20.6		25.1		18.9		19.1
Total other long-term liabilities	$	285.7	$	301.6	$	284.0	$	295.6

Note 5 - Investments in Unconsolidated Affiliates

Variable Interest Entity

Crestwood Permian is a joint venture owned by Crestwood Infrastructure Holdings LLC (Crestwood Infrastructure), our wholly-owned subsidiary, and an affiliate of First Reserve Management, L.P. (First Reserve). We manage and account for our 50% ownership interest in Crestwood Permian, which is a variable interest entity, under the equity method of accounting as we exercise significant influence, but do not control Crestwood Permian and we are not its primary beneficiary due to First Reserve’s rights to exercise control over the entity.

18

Net Investments and Earnings

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

	Investment				Earnings (Loss) from Unconsolidated Affiliates						Earnings (Loss) from Unconsolidated Affiliates
	June 30,		December 31,		Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		2020			2019			2020			2019
Stagecoach Gas Services LLC(1)	$	802.8	$	814.4	$	9.2		$	6.4		$	18.4		$	13.4
Crestwood Permian Basin Holdings LLC(2)	114.7		121.8		(1.0		)	(3.3		)	(0.2		)	(6.7		)
Tres Palacios Holdings LLC(3)	40.6		35.9		0.1			0.1			0.1			0.3
Powder River Basin Industrial Complex, LLC(4)	3.8		8.3		0.1			—			(4.4		)	(0.1		)
Jackalope Gas Gathering Services, L.L.C.(5)	—		—		—			0.5			—			3.7
Total	$	961.9	$	980.4	$	8.4		$	3.7		$	13.9		$	10.6

(1) As of June 30, 2020, our equity in the underlying net assets of Stagecoach Gas Services LLC (Stagecoach Gas) exceeded our investment balance by approximately $51.3 million. This excess amount is entirely attributable to goodwill and, as such, is not subject to amortization. Our Stagecoach Gas investment is included in our storage and transportation segment.

(2) As of June 30, 2020, our equity in the underlying net assets of Crestwood Permian exceeded our investment balance by $9.7 million, and this excess amount is not subject to amortization. Our Crestwood Permian investment is included in our gathering and processing segment.

(3) As of June 30, 2020, our equity in the underlying net assets of Tres Palacios Holdings LLC (Tres Holdings) exceeded our investment balance by approximately $23.4 million. Our Tres Holdings investment is included in our storage and transportation segment.

(4) As of June 30, 2020, our equity in the underlying net assets of Powder River Basin Industrial Complex, LLC (PRBIC) approximates our investment balance. During the first quarter of 2020, we recorded our share of a long-lived asset impairment recorded by our PRBIC equity investment, which eliminated our $5.5 million historical basis difference between our investment balance and the equity in the underlying net assets of PRBIC, and also resulted in a $4.5 million reduction in our earnings from unconsolidated affiliates during the six months ended June 30, 2020. Our PRBIC investment is included in our storage and transportation segment.

(5) On April 9, 2019, Crestwood Niobrara acquired Williams 50% equity interest in Jackalope, and as a result, Crestwood Niobrara controls and owns 100% of the equity interests in Jackalope. As a result of this transaction, we eliminated our historical equity investment in Jackalope and began consolidating Jackalope’s operations. Our Jackalope investment was included in our gathering and processing segment.

Summarized Financial Information of Unconsolidated Affiliates

Below is the summarized operating results for our significant unconsolidated affiliates (in millions; amounts represent 100% of unconsolidated affiliate information):

	Six Months Ended June 30,
	2020							2019
	Operating Revenues		Operating Expenses		Net Income (Loss)			Operating Revenues		Operating Expenses		Net Income (Loss)
Stagecoach Gas	$	75.6	$	38.9	$	36.8		$	79.1	$	40.4	$	38.9
Other(1)	53.5		76.1		(21.6		)	55.4		62.2		(7.9		)
Total	$	129.1	$	115.0	$	15.2		$	134.5	$	102.6	$	31.0

(1) Includes our Crestwood Permian, Tres Holdings and PRBIC equity investments during the six months ended June 30, 2020 and 2019, and our Jackalope equity investment during the six months ended June 30, 2019 (prior to the acquisition of the remaining 50% equity interest from Williams in April 2019). We amortize the excess basis in certain of our equity investments as an increase in our earnings from unconsolidated affiliates. We recorded amortization of the excess basis in our Tres Holdings equity investment of $0.6 million during both the six months ended June 30, 2020 and 2019. We recorded amortization of the excess basis in our PRBIC equity investment of $0.2 million during the six months ended June 30, 2019. We recorded amortization of the excess basis in the Jackalope equity investment of less than $0.1 million during the six months ended June 30, 2019.

19

Distributions and Contributions

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

	Distributions(1)				Contributions
	Six Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
Stagecoach Gas	$	30.0	$	25.4	$	—	$	—
Crestwood Permian	6.7		2.9		—		10.0
Tres Holdings	1.4		1.2		6.0		6.3
PRBIC	0.1		—		—		0.2
Jackalope	—		11.6		—		24.4
Total	$	38.2	$	41.1	$	6.0	$	40.9

(1) In July 2020, we received cash distributions from Stagecoach Gas, Crestwood Permian and Tres Holdings of approximately $14.5 million, $1.8 million and $3.0 million, respectively.

Other

Contingent Consideration. Pursuant to the Stagecoach Gas limited liability company agreement, we may be required to make payments of up to $57 million to Con Edison Gas Pipeline and Storage Northeast, LLC after December 31, 2020 if certain criteria are not met by Stagecoach Gas by December 31, 2020, including achieving certain performance targets on growth capital projects. These growth capital projects depend on the construction of third-party expansion projects, and those third-party projects experienced regulatory and other delays that caused Stagecoach Gas to delay its growth capital projects. As a result, our consolidated balance sheet at June 30, 2020 reflects a $19 million current liability included in accrued expenses and other liabilities and a $38 million other long-term liability related to the anticipated settlement of this obligation.

Guarantee. CEQP issued a guarantee under which CEQP would be required to pay up to $10 million if Crestwood Permian fails to honor its obligations to Crestwood Permian Basin LLC, a 50% equity investment of Crestwood Permian, in the event Crestwood Permian Basin LLC fails to satisfy its obligations under its gas gathering agreement. We do not believe that it is probable that this guarantee will result in future losses based on our assessment of the nature of the guarantee, the financial condition of the guaranteed party and the period of time that the guarantee has been outstanding, and as a result, we have not recorded a liability on our consolidated balance sheets at June 30, 2020 and December 31, 2019.

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.

Commodity Derivative Instruments and Price Risk Management

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 costs of product sold in our consolidated statements of operations. The following table summarizes the impact to our consolidated statements of operations related to our commodity-based derivatives reflected in operating revenues and costs of product/services sold during the three and six months ended June 30, 2020 and 2019 (in millions):

20

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2020		2019		2020		2019
Product revenues	$	18.0	$	40.2	$	93.0	$	144.3
Gain reflected in costs of product/services sold	$	6.8	$	9.9	$	28.8	$	7.0

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 costs of product/services sold related to these instruments.

Commodity Price and Credit Risk

Notional Amounts and Terms

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

	June 30, 2020		December 31, 2019
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, ethane, butane, heating oil and crude oil (MMBbls)	64.4	69.8	33.5	36.6
Natural gas (Bcf)	10.2	17.5	3.7	8.7

Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly, notional amounts do not reflect our monetary exposure to market or credit risks. All contracts subject to price risk had a maturity of 37 months or less; however, 83% 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. For example, in June 2020, Chesapeake Energy Corporation (Chesapeake), our major customer in the Powder River Basin, filed for protection under Chapter 11 of the U.S. Bankruptcy Code and in July 2020, Bruin E&P Partners, LLC (Bruin), our major customer in the Bakken also filed for protection under Chapter 11 of the U.S. Bankruptcy Code.  Chesapeake and Bruin were current on all amounts due to us as of June 30, 2020 and we obtained letters of credit from Chesapeake to provide additional cash flow protection related to their credit risk. 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 New York Mercantile Exchange (NYMEX) broker related to our net asset or liability position with such 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.

21

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

	June 30, 2020		December 31, 2019
Aggregate fair value of derivative instruments with credit-risk-related contingent features(1)	$	20.3	$	1.6
NYMEX-related net derivative asset (liability) position	$	1.9	$	(28.8	)
NYMEX-related cash collateral posted	$	26.8	$	40.4
Cash collateral received, net	$	21.1	$	16.9

(1) At June 30, 2020 and December 31, 2019, we posted less than $0.1 million of collateral associated with these derivatives.

Note 7 – Fair Value Measurements

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

• Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of financial instruments such as exchange-traded derivatives, listed equities and US government treasury securities.

• Level 2—Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives such as over the counter (OTC) forwards, options and physical exchanges.

• Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

Cash, Accounts Receivable and Accounts Payable

As of June 30, 2020 and December 31, 2019, the carrying amounts of cash, accounts receivable and accounts payable approximate fair value based on the short-term nature of these instruments.

Credit Facility

The fair value of the amounts outstanding under our Crestwood Midstream credit facility approximates the carrying amounts as of June 30, 2020 and December 31, 2019, due primarily to the variable nature of the interest rate of the instrument, which is considered a Level 2 fair value measurement.

22

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, 2020				December 31, 2019
	Carrying  Amount		Fair Value		Carrying  Amount		Fair Value
2023 Senior Notes	$	695.9	$	623.0	$	695.1	$	714.0
2025 Senior Notes	$	495.0	$	435.0	$	494.4	$	514.4
2027 Senior Notes	$	592.6	$	499.2	$	592.1	$	610.1

Financial Assets and Liabilities

As of June 30, 2020 and December 31, 2019, 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 heating oil, crude oil, NGLs and natural gas. Our derivative instruments consist of forwards, swaps, futures, physical exchanges and options.

Our derivative instruments that are traded on the NYMEX have been categorized as Level 1.

Our derivative instruments also include OTC contracts, which are not traded on a public exchange. The fair values of these derivative instruments are determined based on inputs that are readily available in public markets or can be derived from information available in publicly quoted markets. These instruments have been categorized as Level 2.

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

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

The following tables set forth by level within the fair value hierarchy, our financial instruments that were accounted for at fair value on a recurring basis at June 30, 2020 and December 31, 2019 (in millions):

	June 30, 2020
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting(1)			Collateral/Margin Received or Paid		Fair Value
Assets
Assets from price risk management	$	26.2	$	187.8	$	—	$	214.0	$	(186.3	)	$	16.7	$	44.4
Suburban Propane Partners, L.P. units(2)	2.0		—		—		2.0		—			—		2.0
Total assets at fair value	$	28.2	$	187.8	$	—	$	216.0	$	(186.3	)	$	16.7	$	46.4
Liabilities
Liabilities from price risk management	$	29.7	$	177.8	$	—	$	207.5	$	(186.3	)	$	11.0	$	32.2
Total liabilities at fair value	$	29.7	$	177.8	$	—	$	207.5	$	(186.3	)	$	11.0	$	32.2

23

	December 31, 2019
	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	$	3.7	$	164.0	$	—	$	167.7	$	(122.3	)	$	(2.2	)	$	43.2
Suburban Propane Partners, L.P. units(2)	3.1		—		—		3.1		—			—			3.1
Total assets at fair value	$	6.8	$	164.0	$	—	$	170.8	$	(122.3	)	$	(2.2	)	$	46.3
Liabilities
Liabilities from price risk management	$	2.8	$	151.9	$	—	$	154.7	$	(122.3	)	$	(25.7	)	$	6.7
Total liabilities at fair value	$	2.8	$	151.9	$	—	$	154.7	$	(122.3	)	$	(25.7	)	$	6.7

(1) Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions.

(2) Amount is reflected in other assets on CEQP’s consolidated balance sheets.

Note 8 – Long-Term Debt

Long-term debt consisted of the following at June 30, 2020 and December 31, 2019 (in millions):

	June 30, 2020		December 31, 2019
Credit Facility	$	801.2	$	557.0
2023 Senior Notes	700.0		700.0
2025 Senior Notes	500.0		500.0
2027 Senior Notes	600.0		600.0
Other	0.6		0.6
Less: deferred financing costs, net	25.9		29.1
Total debt	2,575.9		2,328.5
Less: current portion	0.2		0.2
Total long-term debt, less current portion	$	2,575.7	$	2,328.3

Credit Facility

At June 30, 2020, Crestwood Midstream had $424.9 million of available capacity under its credit facility considering the most restrictive debt covenants in its credit agreement. At June 30, 2020 and December 31, 2019, Crestwood Midstream’s outstanding standby letters of credit were $23.9 million and $31.7 million. Borrowings under the credit facility accrue interest at prime or Eurodollar based rates plus applicable spreads, which resulted in interest rates between 2.43% and 4.50% at June 30, 2020 and 3.96% and 6.00% at December 31, 2019. The weighted-average interest rate on outstanding borrowings as of June 30, 2020 and December 31, 2019 was 2.44% and 4.00%.

Crestwood Midstream is required under its credit agreement to maintain a net debt to consolidated EBITDA ratio (as defined in its credit agreement) of not more than 5.50 to 1.0, a consolidated EBITDA to consolidated interest expense ratio (as defined in its credit agreement) of not less than 2.50 to 1.0, and a senior secured leverage ratio (as defined in its credit agreement) of not more than 3.75 to 1.0. At June 30, 2020, the net debt to consolidated EBITDA ratio was approximately 4.16 to 1.0, the consolidated EBITDA to consolidated interest expense ratio was approximately 4.62 to 1.0, and the senior secured leverage ratio was 1.28 to 1.0.

Senior Notes

In April 2019, Crestwood Midstream issued $600 million of 5.625% unsecured senior notes due 2027 (the 2027 Senior Notes). The 2027 Senior Notes mature on May 1, 2027, and interest is payable semi-annually in arrears on May 1 and November 1 of each year, beginning on November 1, 2019. The net proceeds from this offering of approximately $591.1 million were used to

24

repay a portion of the outstanding borrowings under our credit facility, which included approximately $250 million which was used to fund the acquisition of the remaining 50% equity interest in Jackalope.

Note 9 - Earnings Per Limited Partner Unit

Our net income (loss) attributable to Crestwood Equity Partners is allocated to the subordinated and limited partner unitholders based on their ownership percentage after giving effect to net income attributable to the preferred units. We calculate basic net income per limited partner unit using the two-class method. Diluted net income per limited partner unit is computed using the treasury stock method, which considers the impact to net income 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 on net income attributable to Crestwood Equity Partners per limited partner unit 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, 2020 and 2019 (in millions):

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Preferred units (1)	7.1	—	7.1	7.1
Crestwood Niobrara’s preferred units(1)	8.2	—	8.2	—
Unit-based compensation performance units(1)	0.2	—	0.3	—
Subordinated units(1)	0.4	—	0.4	—

(1) For additional information regarding the potential conversion/redemption of our preferred units and Crestwood Niobrara’s preferred units to CEQP common units, and of our performance units and subordinated units, see our 2019 Annual Report on Form 10-K.

The table below shows CEQP’s net income per limited partner unit based on the number of basic and diluted limited partner units outstanding for the three and six months ended June 30, 2020 and 2019 (in millions, except for per unit data):

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2020			2019		2020			2019
Common unitholders’ interest in net income (loss)	$	(49.5	)	$	198.2	$	(97.8	)	$	193.3
Dilutive effect of net income attributable to preferred units	—			15.0		—			—
Dilutive effect of net income attributable to subordinated units	—			1.2		—			1.2
Diluted net income (loss)	$	(49.5	)	$	214.4	$	(97.8	)	$	194.5
Weighted-average limited partners’ units outstanding - basic	73.2			71.8		73.0			71.8
Dilutive effect of preferred units	—			7.1		—			—
Dilutive effect of Crestwood Niobrara preferred units	—			3.4		—			4.5
Dilutive effect of stock-based compensation performance units	—			0.3		—			0.3
Dilutive effect of subordinated units	—			0.4		—			0.4
Weighted-average limited partners’ units outstanding - diluted	73.2			83.0		73.0			77.0
Basic earnings per unit:
Net income (loss) per limited partner unit	$	(0.68	)	$	2.76	$	(1.34	)	$	2.69
Diluted earnings per unit:
Net income (loss) per limited partner unit	$	(0.68	)	$	2.58	$	(1.34	)	$	2.53

25

Note 10 – Partners’ Capital

Common Units

Effective April 1, 2020, we suspended the equity distribution program with certain financial institutions under which we were allowed to offer and sell, from time to time through one or more of these financial institutions, common units having an aggregate offering price of up to $250 million. We did not issue any common units under this program during the six months ended June 30, 2020 and 2019.

Distributions

Crestwood Equity

Limited Partners. A summary of CEQP’s limited partner quarterly cash distributions for the six months ended June 30, 2020 and 2019 is presented below:

Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2020
February 7, 2020	February 14, 2020	$	0.625	$	45.3
May 8, 2020	May 15, 2020	0.625		45.7
				$	91.0
2019
February 7, 2019	February 14, 2019	$	0.60	$	43.1
May 8, 2019	May 15, 2019	0.60		43.1
				$	86.2

On July 16, 2020, we declared a distribution of $0.625 per limited partner unit to be paid on August 14, 2020 to unitholders of record on August 7, 2020 with respect to the quarter ended June 30, 2020.

Preferred Unitholders. During the six months ended June 30, 2020 and 2019, we made cash distributions to our preferred unitholders of approximately $30.0 million in both periods. On July 16, 2020, the board of directors of our general partner authorized a cash distribution to our preferred unitholders of approximately $15.0 million for the quarter ended June 30, 2020.

Crestwood Midstream

During the six months ended June 30, 2020 and 2019, Crestwood Midstream paid cash distributions of $119.0 million and $117.5 million to Crestwood Equity.

Non-Controlling Partner

Crestwood Niobrara issued preferred interests to Jackalope Holdings, which are reflected as non-controlling interest in subsidiary apart from partners’ capital (i.e., temporary equity) on our consolidated balance sheets. In April 2019, Crestwood Niobrara issued $235 million in new preferred interests (Series A-3 Preferred Units) to Jackalope Holdings in conjunction with Crestwood Niobrara’s acquisition of the remaining 50% equity interest in Jackalope from Williams, at which time we began classifying our non-controlling interest in subsidiary apart from partners’ capital. We adjust the carrying amount of our non-controlling interest to its redemption value each period through net income attributable to non-controlling partner.

The following table shows the change in our non-controlling interest in subsidiary at June 30, 2020 and 2019 (in millions):

Balance at December 31, 2019	$	426.2
Contributions from non-controlling partner	2.8
Distributions to non-controlling partner	(18.5		)
Net income attributable to non-controlling partner	20.1
Balance at June 30, 2020	$	430.6

26

Balance at December 31, 2018	$	—
Reclassification of Series A-2 Preferred Units	178.8
Issuance of Series A-3 Preferred Units	235.0
Net income attributable to non-controlling partner	10.6
Balance at June 30, 2019	$	424.4

Crestwood Niobrara makes quarterly cash distributions on its preferred interests within 30 days after the end of each quarter. During the six months ended June 30, 2020 and 2019, Crestwood Niobrara paid cash distributions of $18.5 million and $6.6 million to Jackalope Holdings. In July 2020, Crestwood Niobrara paid cash distributions to Jackalope Holdings of approximately$9.3 million for the quarter ended June 30, 2020. During the six months ended June 30, 2020, we received contributions of $2.8 million from our non-controlling partner to fund our Jackalope expansion projects.

Other

In February 2020, Crestwood Equity issued 184,528 performance units under the Crestwood Equity Partners LP Long Term Incentive Plan (Crestwood LTIP). The performance units are designed to provide an incentive for continuous employment to certain key employees. The vesting of performance units is subject to the attainment of certain performance and market goals over a three-year period, and entitle a participant to receive common units of Crestwood Equity without payment of an exercise price upon vesting. As of June 30, 2020, we had total unamortized compensation expense of approximately $3.7 million related to these performance units, which we expect will be amortized during the next three years. During the three and six months ended June 30, 2020, we recognized compensation expense of approximately $0.6 million and $0.8 million related to these performance units, which is included in general and administrative expenses on our consolidated statements of operations.

During the six months ended June 30, 2020, 405,620 performance units that were previously issued under the Crestwood LTIP vested, and as a result of the attainment of certain performance and market goals and related distributions during the three years that the awards were outstanding, we issued 838,556 common units during the six months ended June 30, 2020 related to those performance units.

Note 11 – 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. Linde claims damages of $55 million in unpaid invoices and other damages. This matter is not an insurable event based on our insurance policies, and we are unable to predict the outcome for this matter.

General. We are periodically involved in litigation proceedings. If we determine that a negative outcome is probable and the amount of loss is reasonably estimable, then we accrue the estimated amount. The results of litigation proceedings cannot be predicted with certainty. We could incur judgments, enter into settlements or revise our expectations regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations or cash flows in the period in which the amounts are paid and/or accrued. As of June 30, 2020 and December 31, 2019, we had approximately $10.9 million and $10.7 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.

27

Regulatory Compliance

In the ordinary course of our business, we are subject to various laws and regulations. In the opinion of our management, compliance with current laws and regulations will not have a material effect on our results of operations, cash flows or financial condition.

Environmental Compliance

Our operations are subject to stringent and complex laws and regulations pertaining to worker health, safety, and the environment. We are subject to laws and regulations at the federal, state, regional and local levels that relate to air and water quality, hazardous and solid waste management and disposal, and other environmental matters. The cost of planning, designing, constructing and operating our facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures.

During 2014, we experienced three releases totaling approximately 28,000 barrels of produced water on our Arrow water gathering system located on the Fort Berthold Indian Reservation in North Dakota. We immediately notified the National Response Center, the Three Affiliated Tribes and numerous other regulatory authorities. Thereafter, we contained and cleaned up the releases, and placed the impacted segments of these water lines back into service. In May 2015, we experienced a release of approximately 5,200 barrels of produced water on our Arrow water gathering system, immediately notified numerous regulatory authorities and other third parties, and thereafter contained and cleaned up the releases.

In August 2015, we received a notice of violation from the Three Affiliated Tribes’ Environmental Division related to our 2014 produced water releases on the Fort Berthold Indian Reservation. The notice of violation imposes fines and requests reimbursements exceeding $1.1 million; however, the notice of violation was stayed on September 15, 2015. Our discussions regarding the notice of violation continue with the Three Affiliated Tribes.

During September 2019, we experienced two produced water releases totaling approximately 5,000 barrels on our Arrow system located on the Fort Berthold Indian Reservation in North Dakota.  We immediately notified the National Response Center, the State of North Dakota, the Three Affiliated Tribes, affected landowners and numerous other regulatory authorities. We are substantially complete with the remediation efforts and continue to monitor the impact of both spills.

In response to the water releases on our Arrow system, we removed approximately 30 miles of water gathering pipeline from service. In addition, we are currently in the process of replacing certain sections of our water gathering pipeline with pipeline composed of higher capacity material that is more suitable to the environment and climate conditions in the Bakken, which will increase water gathering capacity on the Arrow system and further our commitment to sustainability and environmental stewardship in the areas where we live and operate.

We will continue our remediation efforts to ensure the impacted lands are restored to their prior state. We believe these releases are insurable events under our policies, and we have notified our carriers of these events. We have not recorded an insurance receivable as of June 30, 2020.

At June 30, 2020 and December 31, 2019, our accrual of approximately $3.8 million and $6.7 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 $3.8 million to $8.0 million at June 30, 2020.

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

28

evaluation of these qualitative data points. We are liable for the development of claims for our disposed retail propane operations, provided they were reported prior to August 1, 2012. The following table summarizes CEQP’s and CMLP’s self-insurance reserves at June 30, 2020 and December 31, 2019 (in millions):

	CEQP				CMLP
	June 30, 2020		December 31, 2019		June 30, 2020		December 31, 2019
Self-insurance reserves(1)	$	9.4	$	9.7	$	8.3	$	8.3

(1) At June 30, 2020, CEQP and CMLP classified approximately $6.2 million and $5.2 million, respectively of these reserves as other long-term liabilities on their consolidated balance sheets.

Leases

The following table summarizes the balance sheet information related to our operating and finance leases at June 30, 2020 and December 31, 2019 (in millions):

	June 30,		December 31,
	2020		2019
Operating Leases
Operating lease right-of-use assets, net	$	44.2	$	53.8
Accrued expenses and other liabilities	$	17.8	$	18.1
Long-term operating lease liabilities	32.9		41.5
Total operating lease liabilities	$	50.7	$	59.6
Finance Leases
Property, plant and equipment	$	14.9	$	14.9
Less: accumulated depreciation	7.2		5.4
Property, plant and equipment, net	$	7.7	$	9.5
Accrued expenses and other liabilities	$	3.3	$	3.2
Other long-term liabilities	3.6		5.2
Total finance lease liabilities	$	6.9	$	8.4

Lease expense. Our operating lease expense, net totaled $7.1 million and $7.3 million for the three months ended June 30, 2020 and 2019 and $14.6 million for both the six months ended June 30, 2020 and 2019. Our finance lease expense totaled $1.1 million for both the three months ended June 30, 2020 and 2019 and $2.2 million for both the six months ended June 30, 2020 and 2019.

Guarantees and Indemnifications

We are involved in various joint ventures that sometimes require financial and performance guarantees. In a financial guarantee, we are obligated to make payments if the guaranteed party fails to make payments under, or violates the terms of, the financial arrangement. In a performance guarantee, we provide assurance that the guaranteed party will execute on the terms of the contract. If they do not, we are required to perform on their behalf. We also periodically provide indemnification arrangements related to assets or businesses we have sold. For a further description of our guarantees associated with our joint ventures, see Note 5.

Our potential exposure under guarantee and indemnification arrangements can range from a specified amount to an unlimited dollar amount, depending on the nature of the claim, specificity as to duration, and the particular transaction. As of June 30, 2020 and December 31, 2019, we have no amounts accrued for these guarantees.

Note 12 – Related Party Transactions

Crestwood Holdings LLC (Crestwood Holdings) indirectly owns both CEQP’s and CMLP’s general partner. The affiliates of Crestwood Holdings and its owners are considered CEQP’s and CMLP’s related parties. We enter into transactions with our affiliates within the ordinary course of business, including gas gathering and processing services, product purchases, marketing

29

services and various operating agreements. We also enter into transactions with our affiliates related to services provided on our expansion projects. During the six months ended June 30, 2020 and 2019, we paid approximately $2.9 million and $5.1 million of capital expenditures to Applied Consultants, Inc., an affiliate of Crestwood Holdings.

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 2019 Annual Report on Form 10-K.

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2020			2019			2020		2019
Revenues at CEQP and CMLP(1)	$	7.5		$	1.3		$	15.0	$	2.5
Costs of product/services sold at CEQP and CMLP(2)	$	3.6		$	0.9		$	6.8	$	35.3
Operations and maintenance expenses charged by CEQP and CMLP(3)	$	5.5		$	5.9		$	11.7	$	13.4
General and administrative expenses charged by CEQP to CMLP, net(4)	$	10.9		$	10.1		$	18.0	$	21.1
General and administrative expenses at CEQP charged to (from) Crestwood Holdings, net(5)	$	(1.5	)	$	(0.1	)	$	11.3	$	(5.3	)

(1) Includes $7.5 million and $15.0 million during the three and six months ended June 30, 2020 related to the sale of NGLs to a subsidiary of Crestwood Permian and $1.3 million and $2.5 million during the three and six months ended June 30, 2019 related to the sale of natural gas to a subsidiary of Stagecoach Gas.

(2) Includes (i) $3.2 million and $6.4 million during the three and six months ended June 30, 2020 and $0.9 million and $9.1 million during the three and six months ended June 30, 2019 related to purchases of NGLs from a subsidiary of Crestwood Permian; (ii) $0.1 million during both the three and six months ended June 30, 2020 related to purchases from a subsidiary of Tres Palacios Holdings, (iii) less than $0.1 million and $2.3 million during the three and six months ended June 30, 2019 related to purchases of natural gas from a subsidiary of Stagecoach Gas; and (iv) $0.3 million during both the three and six months ended June 30, 2020 and less than $0.1 million and $23.9 million during the three and six months ended June 30, 2019 related to an agency marketing agreement with Ascent Resources - Utica, LLC, an affiliate of Crestwood Holdings.

(3) We have operating agreements with certain of our unconsolidated affiliates pursuant to which we charge them operations and maintenance expenses in accordance with their respective agreements, and these charges are reflected as a reduction of operations and maintenance expenses in our consolidated statements of operations. During the three and six months ended June 30, 2020, we charged $1.6 million and $3.3 million to Stagecoach Gas, $1.1 million and $2.2 million to Tres Palacios, and $2.8 million and $6.2 million to Crestwood Permian under these agreements. During the three and six months ended June 30, 2019, we charged $1.9 million and $3.9 million to Stagecoach Gas, $1.0 million and $2.2 million to Tres Palacios, and $3.0 million and $6.8 million to Crestwood Permian. During the six months ended June 30, 2019, we charged $0.5 million to Jackalope under an operating agreement prior to our acquisition of the remaining 50% equity interest in Jackalope in Williams.

(4) Includes $11.9 million and $20.1 million of unit-based compensation charges allocated from CEQP to CMLP for the three and six months ended June 30, 2020 and $11.0 million and $22.9 million for the three and six months ended June 30, 2019. In addition, includes $1.0 million and $2.1 million of CMLP’s general and administrative costs allocated to CEQP during the three and six months ended June 30, 2020 and $0.9 million and $1.8 million during the three and six months ended June 30, 2019.

(5) Includes $1.7 million of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the three months ended June 30, 2020, a $10.9 million reduction of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the six months ended June 30, 2020 and $0.2 million and $5.6 million of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the three and six months ended June 30, 2019. In addition, includes $0.2 million and $0.4 million of CEQP’s general and administrative costs allocated to Crestwood Holdings during the three and six months ended June 30, 2020 and $0.1 million and $0.3 million during the three and six months ended June 30, 2019.

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

	June 30, 2020		December 31, 2019
Accounts receivable at CEQP and CMLP	$	10.9	$	7.3
Accounts payable at CEQP	$	6.9	$	15.6
Accounts payable at CMLP	$	4.5	$	13.1

30

Note 13 – Segments

Financial Information

We have three operating and reportable segments: (i) gathering and processing operations; (ii) storage and transportation operations; and (iii) marketing, supply and logistics operations. Our corporate operations include all general and administrative expenses that are not allocated to our reportable segments. We assess the performance of our operating segments based on EBITDA, which is defined as income before income taxes, plus interest and debt expense, net and depreciation, amortization and accretion expense.

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

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2020			2019		2020			2019
Net income (loss)	$	(24.3	)	$	225.0	$	(47.7	)	$	239.1
Add:
Interest and debt expense, net	34.0			27.8		66.6			52.7
Provision (benefit) for income taxes	(0.1		)	0.3		(0.1		)	0.3
Depreciation, amortization and accretion	61.0			49.3		117.1			89.1
EBITDA	$	70.6		$	302.4	$	135.9		$	381.2

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

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2020			2019		2020			2019
Net income (loss)	$	(26.8	)	$	222.9	$	(52.4	)	$	234.5
Add:
Interest and debt expense, net	34.0			27.8		66.6			52.7
Provision (benefit) for income taxes	(0.2		)	0.3		(0.2		)	0.3
Depreciation, amortization and accretion	64.6			52.7		124.2			96.1
EBITDA	$	71.6		$	303.7	$	138.2		$	383.6

The following tables summarize CEQP’s and CMLP’s reportable segment data for the three and six months ended June 30, 2020 and 2019 (in millions). Intersegment revenues included in the following tables are accounted for as arms-length transactions that apply our revenue recognition policies as described in our 2019 Annual Report on Form 10-K. Included in earnings from unconsolidated affiliates, net below was approximately $9.5 million and $10.3 million of our proportionate share of interest expense, depreciation and amortization expense and gains (losses) on long-lived assets, net recorded by our equity investments for the three months ended June 30, 2020 and 2019 and $23.3 million and $23.0 million for the six months ended June 30, 2020 and 2019.

31

Crestwood Equity

	Three Months Ended June 30, 2020
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	114.5		$	3.1	$	235.1		$	—		$	352.7
Intersegment revenues	14.3			2.4		(16.7		)	—			—
Costs of product/services sold	21.3			0.1		204.3			—			225.7
Operations and maintenance expense	19.3			0.7		11.6			—			31.6
General and administrative expense	—			—		—			29.5			29.5
Loss on long-lived assets, net	(3.6		)	—		(0.2		)	—			(3.8		)
Earnings (loss) from unconsolidated affiliates, net	(1.0		)	9.4		—			—			8.4
Other income, net	—			—		—			0.1			0.1
EBITDA	$	83.6		$	14.1	$	2.3		$	(29.4	)	$	70.6
Goodwill	$	45.9		$	—	$	92.7		$	—		$	138.6
Total assets	$	3,589.8		$	964.7	$	736.9		$	32.3		$	5,323.7

	Three Months Ended June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	199.7		$	4.9	$	478.8		$	—		$	683.4
Intersegment revenues	25.4			3.2		(28.6		)	—			—
Costs of product/services sold	108.9			—		428.3			—			537.2
Operations and maintenance expense	24.6			0.9		9.2			—			34.7
General and administrative expense	—			—		—			22.3			22.3
Gain (loss) on long-lived assets, net	(0.2		)	—		—			0.2			—
Gain on acquisition	209.4			—		—			—			209.4
Earnings (loss) from unconsolidated affiliates, net	(2.8		)	6.5		—			—			3.7
Other income, net	—			—		—			0.1			0.1
EBITDA	$	298.0		$	13.7	$	12.7		$	(22.0	)	$	302.4

32

	Six Months Ended June 30, 2020
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	329.4		$	6.6	$	744.6		$	—		$	1,080.6
Intersegment revenues	54.3			5.0		(59.3		)	—			—
Costs of product/services sold	129.6			0.3		630.2			—			760.1
Operations and maintenance expense	46.3			2.1		20.8			—			69.2
General and administrative expense	—			—		—			44.4			44.4
Loss on long-lived assets, net	(4.6		)	—		(0.2		)	—			(4.8		)
Goodwill impairment	(80.3		)	—		—			—			(80.3		)
Earnings (loss) from unconsolidated affiliates, net	(0.2		)	14.1		—			—			13.9
Other income, net	—			—		—			0.2			0.2
EBITDA	$	122.7		$	23.3	$	34.1		$	(44.2	)	$	135.9
Goodwill	$	45.9		$	—	$	92.7		$	—		$	138.6
Total assets	$	3,589.8		$	964.7	$	736.9		$	32.3		$	5,323.7

	Six Months Ended June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	382.0		$	12.7	$	1,123.9		$	—		$	1,518.6
Intersegment revenues	78.2			6.8		(85.0		)	—			—
Costs of product/services sold	246.9			—		985.9			—			1,232.8
Operations and maintenance expense	42.7			1.9		18.7			—			63.3
General and administrative expense	—			—		—			59.5			59.5
Gain (loss) on long-lived assets, net	(2.0		)	—		(0.2		)	0.2			(2.0		)
Gain on acquisition	209.4			—		—			—			209.4
Earnings (loss) from unconsolidated affiliates, net	(3.0		)	13.6		—			—			10.6
Other income, net	—			—		—			0.2			0.2
EBITDA	$	375.0		$	31.2	$	34.1		$	(59.1	)	$	381.2

Crestwood Midstream

	Three Months Ended June 30, 2020
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	114.5		$	3.1	$	235.1		$	—		$	352.7
Intersegment revenues	14.3			2.4		(16.7		)	—			—
Costs of product/services sold	21.3			0.1		204.3			—			225.7
Operations and maintenance expense	19.3			0.7		11.6			—			31.6
General and administrative expense	—			—		—			28.4			28.4
Loss on long-lived assets, net	(3.6		)	—		(0.2		)	—			(3.8		)
Earnings (loss) from unconsolidated affiliates, net	(1.0		)	9.4		—			—			8.4
EBITDA	$	83.6		$	14.1	$	2.3		$	(28.4	)	$	71.6
Goodwill	$	45.9		$	—	$	92.7		$	—		$	138.6
Total assets	$	3,742.1		$	964.7	$	736.9		$	28.6		$	5,472.3

33

	Three Months Ended June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	199.7		$	4.9	$	478.8		$	—		$	683.4
Intersegment revenues	25.4			3.2		(28.6		)	—			—
Costs of product/services sold	108.9			—		428.3			—			537.2
Operations and maintenance expense	24.6			0.9		9.2			—			34.7
General and administrative expense	—			—		—			20.9			20.9
Gain (loss) on long-lived assets, net	(0.2		)	—		—			0.2			—
Gain on acquisition	209.4			—		—			—			209.4
Earnings (loss) from unconsolidated affiliates, net	(2.8		)	6.5		—			—			3.7
EBITDA	$	298.0		$	13.7	$	12.7		$	(20.7	)	$	303.7

	Six Months Ended June 30, 2020
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	329.4		$	6.6	$	744.6		$	—		$	1,080.6
Intersegment revenues	54.3			5.0		(59.3		)	—			—
Costs of product/services sold	129.6			0.3		630.2			—			760.1
Operations and maintenance expense	46.3			2.1		20.8			—			69.2
General and administrative expense	—			—		—			41.9			41.9
Loss on long-lived assets, net	(4.6		)	—		(0.2		)	—			(4.8		)
Goodwill impairment	(80.3		)	—		—			—			(80.3		)
Earnings (loss) from unconsolidated affiliates, net	(0.2		)	14.1		—			—			13.9
EBITDA	$	122.7		$	23.3	$	34.1		$	(41.9	)	$	138.2
Goodwill	$	45.9		$	—	$	92.7		$	—		$	138.6
Total assets	$	3,742.1		$	964.7	$	736.9		$	28.6		$	5,472.3

	Six Months Ended June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	382.0		$	12.7	$	1,123.9		$	—		$	1,518.6
Intersegment revenues	78.2			6.8		(85.0		)	—			—
Costs of product/services sold	246.9			—		985.9			—			1,232.8
Operations and maintenance expense	42.7			1.9		18.7			—			63.3
General and administrative expense	—			—		—			56.9			56.9
Gain (loss) on long-lived assets, net	(2.0		)	—		(0.2		)	0.2			(2.0		)
Gain on acquisition	209.4			—		—			—			209.4
Earnings (loss) from unconsolidated affiliates, net	(3.0		)	13.6		—			—			10.6
EBITDA	$	375.0		$	31.2	$	34.1		$	(56.7	)	$	383.6

34

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 totaled $158.3 million and $225.0 million at June 30, 2020 and December 31, 2019, 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 17 years.

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

	June 30, 2020		December 31, 2019
Contract assets (non-current)	$	1.2	$	1.2
Contract liabilities (current)(1)	$	10.2	$	8.8
Contract liabilities (non-current)(1)	$	159.6	$	144.7

(1) During the three and six months ended June 30, 2020, we recognized revenues of approximately $3.1 million and $6.9 million that were previously included in contract liabilities (current) at December 31, 2019. The remaining change in our contract liabilities during the three and six months ended June 30, 2020, 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, 2020 (in millions):

Remainder of 2020	$	52.3
2021	94.1
2022	63.2
2023	8.0
2024	3.3
Total	$	220.9

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, 2020 and 2019 (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.

35

	Three Months Ended June 30, 2020
	Gathering and Processing		Storage and Transportation		Marketing, Supply and Logistics		Intersegment Elimination			Total
Topic 606 revenues
Gathering
Natural gas	$	33.2	$	—	$	—	$	—		$	33.2
Crude oil	17.9		—		—		—			17.9
Water	18.3		—		—		—			18.3
Processing
Natural gas	7.1		—		—		—			7.1
Compression
Natural gas	5.7		—		—		—			5.7
Storage
Crude oil	0.4		1.1		—		(0.8		)	0.7
NGLs	—		—		3.6		—			3.6
Pipeline
Crude oil	—		1.3		—		(0.4		)	0.9
NGLs	—		—		0.2		—			0.2
Transportation
Crude oil	1.5		—		0.3		—			1.8
NGLs	—		—		2.6		—			2.6
Rail Loading
Crude oil	—		2.9		—		(1.2		)	1.7
Product Sales
Natural gas	6.9		—		15.5		(6.8		)	15.6
Crude oil	34.8		—		102.0		(7.1		)	129.7
NGLs	3.0		—		92.4		(0.3		)	95.1
Other	—		0.2		0.2		(0.1		)	0.3
Total Topic 606 revenues	128.8		5.5		216.8		(16.7		)	334.4
Non-Topic 606 revenues(1)	—		—		18.3		—			18.3
Total revenues	$	128.8	$	5.5	$	235.1	$	(16.7	)	$	352.7

(1) Represents revenues primarily related to our commodity-based derivatives. See Note 6 for additional information related to our price risk management activities.

36

	Three Months Ended June 30, 2019
	Gathering and Processing		Storage and Transportation		Marketing, Supply and Logistics		Intersegment Elimination			Total
Topic 606 revenues
Gathering
Natural gas	$	42.9	$	—	$	—	$	—		$	42.9
Crude oil	15.1		—		—		—			15.1
Water	19.0		—		—		—			19.0
Processing
Natural gas	8.1		—		—		—			8.1
Compression
Natural gas	6.2		—		—		—			6.2
Storage
Crude oil	0.5		1.5		—		(0.5		)	1.5
NGLs	—		—		1.3		—			1.3
Pipeline
Crude oil	—		1.5		—		(0.5		)	1.0
Transportation
Crude oil	1.8		—		1.5		—			3.3
NGLs	—		—		2.1		—			2.1
Rail Loading
Crude oil	—		3.9		—		(1.4		)	2.5
Product Sales
Natural gas	10.9		—		7.9		(4.8		)	14.0
Crude oil	110.2		—		291.4		(16.0		)	385.6
NGLs	10.4		—		133.9		(4.5		)	139.8
Other	—		1.2		0.3		(0.9		)	0.6
Total Topic 606 revenues	225.1		8.1		438.4		(28.6		)	643.0
Non-Topic 606 revenues(1)	—		—		40.4		—			40.4
Total revenues	$	225.1	$	8.1	$	478.8	$	(28.6	)	$	683.4

(1) Represents revenues primarily related to our commodity-based derivatives. See Note 6 for additional information related to our price risk management activities.

37

	Six Months Ended June 30, 2020
	Gathering and Processing		Storage and Transportation		Marketing, Supply and Logistics		Intersegment Elimination			Total
Topic 606 revenues
Gathering
Natural gas	$	77.0	$	—	$	—	$	—		$	77.0
Crude oil	44.4		—		—		—			44.4
Water	41.3		—		—		—			41.3
Processing
Natural gas	17.3		—		—		—			17.3
Compression
Natural gas	12.0		—		—		—			12.0
Storage
Crude oil	0.9		1.7		—		(1.2		)	1.4
NGLs	—		—		5.2		—			5.2
Pipeline
Crude oil	—		2.9		—		(0.9		)	2.0
NGLs	—		—		0.2		—			0.2
Transportation
Crude oil	3.5		—		1.9		—			5.4
NGLs	—		—		4.3		—			4.3
Rail Loading
Crude oil	—		6.3		—		(2.6		)	3.7
Product Sales
Natural gas	18.9		—		33.8		(18.5		)	34.2
Crude oil	155.9		—		352.2		(23.4		)	484.7
NGLs	12.5		—		252.7		(12.2		)	253.0
Other	—		0.7		0.7		(0.5		)	0.9
Total Topic 606 revenues	383.7		11.6		651.0		(59.3		)	987.0
Non-Topic 606 revenues(1)	—		—		93.6		—			93.6
Total revenues	$	383.7	$	11.6	$	744.6	$	(59.3	)	$	1,080.6

(1) Represents revenues primarily related to our commodity-based derivatives. See Note 6 for additional information related to our price risk management activities.

38

	Six Months Ended June 30, 2019
	Gathering and Processing		Storage and Transportation		Marketing, Supply and Logistics		Intersegment Elimination			Total
Topic 606 revenues
Gathering
Natural gas	$	73.1	$	—	$	—	$	—		$	73.1
Crude oil	30.4		—		—		—			30.4
Water	35.8		—		—		—			35.8
Processing
Natural gas	10.6		—		—		—			10.6
Compression
Natural gas	12.2		—		—		—			12.2
Storage
Crude oil	1.0		2.9		—		(1.2		)	2.7
NGLs	—		—		2.6		—			2.6
Pipeline
Crude oil	—		3.2		—		(1.2		)	2.0
Transportation
Crude oil	3.3		—		3.0		—			6.3
NGLs	—		—		6.2		—			6.2
Rail Loading
Crude oil	—		11.1		—		(2.8		)	8.3
Product Sales
Natural gas	29.7		—		30.2		(11.4		)	48.5
Crude oil	241.8		—		581.5		(59.3		)	764.0
NGLs	22.3		—		355.4		(7.3		)	370.4
Other	—		2.3		0.3		(1.8		)	0.8
Total Topic 606 revenues	460.2		19.5		979.2		(85.0		)	1,373.9
Non-Topic 606 revenues(1)	—		—		144.7		—			144.7
Total revenues	$	460.2	$	19.5	$	1,123.9	$	(85.0	)	$	1,518.6

(1) Represents revenues primarily related to our commodity-based derivatives. See Note 6 for additional information related to our price risk management activities.

Note 15 – Condensed Consolidating Financial Information

Crestwood Midstream is a holding company (Parent) and owns no operating assets and has no significant operations independent of its subsidiaries. Obligations under Crestwood Midstream’s senior notes and its credit facility are jointly and severally guaranteed by substantially all of its subsidiaries, except for Crestwood Infrastructure, Crestwood Niobrara, Crestwood Pipeline and Storage Northeast LLC, PRBIC and Tres Holdings and their respective subsidiaries (collectively, Non-Guarantor Subsidiaries). Crestwood Midstream Finance Corp., the co-issuer of the senior notes, is Crestwood Midstream’s 100% owned subsidiary and has no material assets, operations, revenues or cash flows other than those related to its service as co-issuer of the Crestwood Midstream senior notes.

The tables below present condensed consolidating financial statements for Crestwood Midstream as Parent on a stand-alone, unconsolidated basis, and Crestwood Midstream’s combined guarantor and combined non-guarantor subsidiaries as of June 30, 2020 and December 31, 2019, and for the three and six months ended June 30, 2020 and 2019.  The financial information may not necessarily be indicative of the results of operations, cash flows or financial position had the subsidiaries operated as independent entities.

39

Crestwood Midstream Partners LP
Condensed Consolidating Balance Sheet
June 30, 2020
(in millions)
(unaudited)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	0.4	$	—	$	5.7	$	—		$	6.1
Accounts receivable	—		146.5		19.3		—			165.8
Inventory	—		88.9		—		—			88.9
Other current assets	—		52.8		0.3		—			53.1
Total current assets	0.4		288.2		25.3		—			313.9
Property, plant and equipment, net	—		2,410.1		783.6		—			3,193.7
Goodwill and intangible assets, net	—		671.2		284.5		—			955.7
Operating lease right-of-use assets, net	—		41.5		2.7		—			44.2
Investments in consolidated affiliates	4,501.0		—		—		(4,501.0		)	—
Investments in unconsolidated affiliates	—		—		961.9		—			961.9
Other non-current assets	—		2.4		0.5		—			2.9
Total assets	$	4,501.4	$	3,413.4	$	2,058.5	$	(4,501.0	)	$	5,472.3
Liabilities and capital
Current liabilities:
Accounts payable	$	—	$	114.6	$	1.5	$	—		$	116.1
Other current liabilities	25.2		114.8		24.8		—			164.8
Total current liabilities	25.2		229.4		26.3		—			280.9
Long-term liabilities:
Long-term debt, less current portion	2,575.7		—		—		—			2,575.7
Other long-term liabilities	—		165.8		118.2		—			284.0
Deferred income taxes	—		0.6		—		—			0.6
Total liabilities	2,600.9		395.8		144.5		—			3,141.2
Interest of non-controlling partner in subsidiary	—		—		430.6		—			430.6
Partners’ capital	1,900.5		3,017.6		1,483.4		(4,501.0		)	1,900.5
Total liabilities and capital	$	4,501.4	$	3,413.4	$	2,058.5	$	(4,501.0	)	$	5,472.3

40

Crestwood Midstream Partners LP
Condensed Consolidating Balance Sheet
December 31, 2019
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	1.8	$	—	$	23.6	$	—		$	25.4
Accounts receivable	—		229.1		12.8		—			241.9
Inventory	—		53.7		—		—			53.7
Other current assets	—		54.6		0.2		—			54.8
Total current assets	1.8		337.4		36.6		—			375.8
Property, plant and equipment, net	—		2,331.3		736.2		—			3,067.5
Goodwill and intangible assets, net	—		650.7		373.4		—			1,024.1
Operating lease right-of-use assets, net	—		51.0		2.8		—			53.8
Investments in consolidated affiliates	4,451.6		—		—		(4,451.6		)	—
Investments in unconsolidated affiliates	—		—		980.4		—			980.4
Other non-current assets	—		1.9		0.5		—			2.4
Total assets	$	4,453.4	$	3,372.3	$	2,129.9	$	(4,451.6	)	$	5,504.0
Liabilities and capital
Current liabilities:
Accounts payable	$	—	$	175.9	$	10.7	$	—		$	186.6
Other current liabilities	25.8		123.9		17.6		—			167.3
Total current liabilities	25.8		299.8		28.3		—			353.9
Long-term liabilities:
Long-term debt, less current portion	2,328.3		—		—		—			2,328.3
Other long-term liabilities	—		174.8		120.8		—			295.6
Deferred income taxes	—		0.7		—		—			0.7
Total liabilities	2,354.1		475.3		149.1		—			2,978.5
Interest of non-controlling partner in subsidiary	—		—		426.2		—			426.2
Partners’ capital	2,099.3		2,897.0		1,554.6		(4,451.6		)	2,099.3
Total liabilities and capital	$	4,453.4	$	3,372.3	$	2,129.9	$	(4,451.6	)	$	5,504.0

41

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Three Months Ended June 30, 2020
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	336.5		$	16.2		$	—		$	352.7
Costs of product/services sold	—			225.5			0.2			—			225.7
Operating expenses and other:
Operations and maintenance	—			26.5			5.1			—			31.6
General and administrative	14.8			13.6			—			—			28.4
Depreciation, amortization and accretion	—			50.3			14.3			—			64.6
Loss on long-lived assets, net	—			2.0			1.8			—			3.8
	14.8			92.4			21.2			—			128.4
Operating income (loss)	(14.8		)	18.6			(5.2		)	—			(1.4		)
Earnings from unconsolidated affiliates, net	—			—			8.4			—			8.4
Interest and debt expense, net	(33.9		)	(0.1		)	—			—			(34.0		)
Equity in net income (loss) of subsidiaries	11.7			—			—			(11.7		)	—
Income (loss) before income taxes	(37.0		)	18.5			3.2			(11.7		)	(27.0		)
Benefit for income taxes	—			0.2			—			—			0.2
Net income (loss)	(37.0		)	18.7			3.2			(11.7		)	(26.8		)
Net income attributable to non-controlling partner in subsidiary	—			—			10.2			—			10.2
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(37.0	)	$	18.7		$	(7.0	)	$	(11.7	)	$	(37.0	)

42

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Three Months Ended June 30, 2019
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	663.2		$	20.2		$	—		$	683.4
Costs of product/services sold	—			537.2			—			—			537.2
Operating expenses:
Operations and maintenance	—			27.5			7.2			—			34.7
General and administrative	9.7			11.2			—			—			20.9
Depreciation, amortization and accretion	—			43.0			9.7			—			52.7
Gain on acquisition	—			—			(209.4		)	—			(209.4		)
	9.7			81.7			(192.5		)	—			(101.1		)
Operating income (loss)	(9.7		)	44.3			212.7			—			247.3
Earnings from unconsolidated affiliates, net	—			—			3.7			—			3.7
Interest and debt expense, net	(28.0		)	0.2			—			—			(27.8		)
Equity in net income (loss) of subsidiaries	250.0			—			—			(250.0		)	—
Income (loss) before income taxes	212.3			44.5			216.4			(250.0		)	223.2
Provision for income taxes	—			(0.3		)	—			—			(0.3		)
Net income (loss)	212.3			44.2			216.4			(250.0		)	222.9
Net income attributable to non-controlling partner in subsidiary	—			—			10.6			—			10.6
Net income (loss) attributable to Crestwood Midstream Partners LP	$	212.3		$	44.2		$	205.8		$	(250.0	)	$	212.3

43

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Six Months Ended June 30, 2020
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	1,036.9		$	43.7		$	—		$	1,080.6
Costs of product/services sold	—			759.9			0.2			—			760.1
Operating expenses and other:
Operations and maintenance	—			58.3			10.9			—			69.2
General and administrative	32.7			9.2			—			—			41.9
Depreciation, amortization and accretion	—			98.1			26.1			—			124.2
Loss on long-lived assets, net	—			3.0			1.8			—			4.8
Goodwill impairment	—			—			80.3			—			80.3
	32.7			168.6			119.1			—			320.4
Operating income (loss)	(32.7		)	108.4			(75.6		)	—			0.1
Earnings from unconsolidated affiliates, net	—			—			13.9			—			13.9
Interest and debt expense, net	(66.3		)	(0.3		)	—			—			(66.6		)
Equity in net income (loss) of subsidiaries	26.5			—			—			(26.5		)	—
Income (loss) before income taxes	(72.5		)	108.1			(61.7		)	(26.5		)	(52.6		)
Benefit for income taxes	—			0.2			—			—			0.2
Net income (loss)	(72.5		)	108.3			(61.7		)	(26.5		)	(52.4		)
Net income attributable to non-controlling partner	—			—			20.1			—			20.1
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(72.5	)	$	108.3		$	(81.8	)	$	(26.5	)	$	(72.5	)

44

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Six Months Ended June 30, 2019
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	1,498.4		$	20.2		$	—		$	1,518.6
Costs of product/services sold	—			1,232.8			—			—			1,232.8
Operating expenses and other:
Operations and maintenance	—			56.1			7.2			—			63.3
General and administrative	28.4			28.5			—			—			56.9
Depreciation, amortization and accretion	—			86.4			9.7			—			96.1
Loss on long-lived assets, net	—			2.0			—			—			2.0
Gain on acquisition	—			—			(209.4		)	—			(209.4		)
	28.4			173.0			(192.5		)	—			8.9
Operating income (loss)	(28.4		)	92.6			212.7			—			276.9
Earnings from unconsolidated affiliates, net	—			—			10.6			—			10.6
Interest and debt expense, net	(52.7		)	—			—			—			(52.7		)
Equity in net income (loss) of subsidiaries	301.0			—			—			(301.0		)	—
Income (loss) before income taxes	219.9			92.6			223.3			(301.0		)	234.8
Provision for income taxes	—			(0.3		)	—			—			(0.3		)
Net income (loss)	219.9			92.3			223.3			(301.0		)	234.5
Net income attributable to non-controlling partner in subsidiary	—			—			14.6			—			14.6
Net income (loss) attributable to Crestwood Midstream Partners LP	$	219.9		$	92.3		$	208.7		$	(301.0	)	$	219.9

45

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2020
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities	$	(96.4	)	$	197.4		$	80.1		$	—		$	181.1
Cash flows from investing activities:
Acquisition, net of cash acquired	—			(162.3		)	—			—			(162.3		)
Purchases of property, plant and equipment	—			(56.2		)	(87.0		)	—			(143.2		)
Investment in unconsolidated affiliates	—			—			(6.0		)	—			(6.0		)
Capital distributions from unconsolidated affiliates	—			—			18.9			—			18.9
Capital distributions from consolidated affiliates	8.2			—			—			(8.2		)	—
Other	—			(0.3		)	—			—			(0.3		)
Net cash provided by (used in) investing activities	8.2			(218.8		)	(74.1		)	(8.2		)	(292.9		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	742.5			—			—			—			742.5
Payments on long-term debt	(498.2		)	—			—			—			(498.2		)
Payments on finance leases	—			(1.6		)	—			—			(1.6		)
Net proceeds from issuance of non-controlling interest	—			—			2.8			—			2.8
Distributions to partners	(119.0		)	—			(18.5		)	—			(137.5		)
Distributions to parent	—			—			(8.2		)	8.2			—
Taxes paid for unit-based compensation vesting	—			(15.5		)	—			—			(15.5		)
Change in intercompany balances	(38.5		)	38.5			—			—			—
Net cash provided by (used in) financing activities	86.8			21.4			(23.9		)	8.2			92.5
Net change in cash	(1.4		)	—			(17.9		)	—			(19.3		)
Cash at beginning of period	1.8			—			23.6			—			25.4
Cash at end of period	$	0.4		$	—		$	5.7		$	—		$	6.1

46

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2019
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities	$	(87.1	)	$	309.5		$	(27.3	)	$	—		$	195.1
Cash flows from investing activities:
Acquisition, net of cash acquired	—			—			(462.1		)	—			(462.1		)
Purchases of property, plant and equipment	—			(127.7		)	(77.0		)	—			(204.7		)
Investment in unconsolidated affiliates	—			—			(40.9		)	—			(40.9		)
Capital distributions from unconsolidated affiliates	—			—			24.2			—			24.2
Capital contributions to consolidated affiliates	(217.1		)	—			—			217.1			—
Other	—			(0.5		)	—			—			(0.5		)
Net cash provided by (used in) investing activities	(217.1		)	(128.2		)	(555.8		)	217.1			(684.0		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	1,544.0			—			—			—			1,544.0
Payments on long-term debt	(1,159.1		)	(0.4		)	—			—			(1,159.5		)
Payments on finance leases	—			(1.9		)	—			—			(1.9		)
Payments for debt-related deferred costs	(9.0		)	—			—			—			(9.0		)
Net proceeds from the issuance of non-controlling interest	—			—			235.0			—			235.0
Distributions to partners	(117.5		)	—			(6.6		)	—			(124.1		)
Contributions from parent	—			—			217.1			(217.1		)	—
Taxes paid for unit-based compensation vesting	—			(10.6		)	—			—			(10.6		)
Change in intercompany balances	30.7			(168.4		)	137.7			—			—
Net cash provided by (used in) financing activities	289.1			(181.3		)	583.2			(217.1		)	473.9
Net change in cash	(15.1		)	—			0.1			—			(15.0		)
Cash at beginning of period	16.5			—			—			—			16.5
Cash at end of period	$	1.4		$	—		$	0.1		$	—		$	1.5

47

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

Our Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the consolidated financial statements and the accompanying footnotes and Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations in our 2019 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 factors that influence the supply of and demand for crude oil, natural gas and NGLs;

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

• weather conditions;

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

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

• the availability of storage for hydrocarbons;

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

• economic conditions;

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

• environmental claims;

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

• interest rates;

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

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

For additional factors that could cause actual results to be materially different from those described in the forward-looking statements, see Part I, Item 1A. Risk Factors of our 2019 Annual Report on Form 10-K and Part II, Item 1A. Risk Factors of this Quarterly Report on Form 10-Q.

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.

48

In the first quarter of 2020, during a period of growing global and US oil supplies, OPEC and Russia failed to agree on a plan to cut production of oil and related commodities to balance the global oil markets. Commensurate with this excess global oil supply market condition, the COVID-19 pandemic caused an unprecedented decrease in global oil demand. Subsequently, Saudi Arabia announced plans to increase production and reduce the prices at which they sell oil. While OPEC, Russia, the United States and other oil and gas producing countries subsequently agreed to collectively decrease production, these events, combined with the impact that the COVID-19 pandemic have contributed to a significant decrease and volatility in prices for oil. The effect of these events was further exacerbated by a shortage in available storage for hydrocarbons in the U.S., which caused the prices for oil to further decrease dramatically in 2020. The resulting low commodity price environment has adversely impacted U.S. producers and other companies in the energy industry.

Despite the recent decline in commodity prices and resulting market conditions, our long-term business strategy has not changed. We have, however, implemented a number of adjustments to our operations and financial strategies in response to these market conditions, including (i) substantially reducing capital expenditures in response to lower development activity by our gathering and processing customers; (ii) realigning our organization to reduce operating and administrative expenses; (iii) engaging with our customers to maintain volumes across our asset portfolio; (iv) optimizing our storage, transportation and marketing assets to take advantage of regional commodity price volatility; and (v) evaluating our debt and equity structure to preserve liquidity and ensure balance sheet strength during this period of uncertainty in the energy and financial markets. Given our efforts over the past few years to improve the partnership’s competitive position in the businesses we operate, manage costs and improve margins, create a stronger balance sheet and implement new operating standards consistent with our Environmental, Social and Governance program, we believe the Company is well positioned to execute its business plan and weather current market conditions.

In light of these events, we anticipate that the decrease in commodity prices will have a negative impact on certain of our gathering and processing segment’s customers. We expect this to result in reduced production volumes in our oil-weighted basins over the next six months and negatively impact our short-term gathering and processing segment results. In June 2020, Chesapeake, our major customer in the Powder River Basin, filed for protection under Chapter 11 of the U.S. Bankruptcy Code and in July 2020, Bruin, our major customer in the Bakken, filed for protection under Chapter 11 of the U.S. Bankruptcy Code. Chesapeake and Bruin were current on all amounts due to us as of June 30, 2020 and additional cash flow protection is in place with Chesapeake via letters of credit. We are well positioned to maintain full operations to Chesapeake and Bruin throughout their bankruptcy proceedings, and we are closely monitoring our exposure to ensure they continue to promptly pay amounts invoiced to them. We also believe that the natural gas, crude and NGL storage and marketing operations in our storage and transportation and marketing, supply and logistics segments could benefit from the current shortage in available storage for hydrocarbons in the U.S. and the price volatility in the commodity markets caused by the current supply and demand imbalances for crude oil and other commodities. In the current market environment, this could offset some portion of the negative impact of lower commodity prices on our gathering and processing segment, resulting in our expectation that our full year 2020 results of operations will be relatively consistent with our consolidated results of operations in 2019, excluding the impairment of goodwill associated with our Powder River Basin operations described in further detail below.

Business Highlights

Below is a discussion of events that highlight our core business and financing activities. Through continued execution of our plan, we have materially improved the strategic and financial position of the Company and expect to capitalize on increasing opportunities in an improving but competitive market environment, which will position us to achieve our chief business objective to create long-term value for our unitholders.

Bakken. In the Bakken, we completed several capital projects to expand natural gas capacity on the Arrow gas gathering system and upgrade our Arrow produced water gathering system, disposal wells and handling facilities, which should allow us to better serve our customer needs. We believe the expansion of our Arrow facilities, including the placing in service of the Bear Den II processing plant in late 2019, allows us to provide greater flow assurance to our producer customers and reduce the flaring of natural gas experienced by producers on the Fort Berthold Indian Reservation.

In July 2020, a U.S. District Court ordered the Dakota Access Pipeline (DAPL) to shutdown due to environmental and permitting issues. On August 5, 2020, the U.S. Court of Appeals for the District of Columbia Circuit ordered that shutdown of DAPL be stayed and set an expedited schedule for briefing by the parties. The Court of Appeals did not stay the lower court’s vacating of the DAPL easement, but asked the lower court to clarify whether the U.S. Army Corps of Engineers (the Army Corps) intends to allow the continued operation of DAPL. The Army Corps has stated that continued operation of DAPL if the easement is vacated will be subject to review by the federal courts. We are actively engaged with our producer customers on the Arrow system to ensure downstream market access for their crude oil volumes. The Arrow gathering system currently connects

49

to the DAPL, Hiland and Tesoro pipelines, providing significant downstream delivery capacity for our Arrow customers. Additionally, we can transport Arrow crude volumes to our COLT Hub facility by pipeline or truck, which mitigates the impact to our producers with the ability to access multiple markets out of the basin.

In response to several produced water releases on our Arrow system over the past few years, during 2019, we removed approximately 30 miles of water gathering pipeline from service. We plan to continue replacing certain sections of our water gathering system with pipeline composed of higher capacity material that is more suitable for the environment and climate conditions in the Bakken. This capital project will increase water gathering capacity on the Arrow system and further our commitment to sustainability and environmental stewardship on the Fort Berthold Indian Reservation.

Powder River Basin. In the Powder River Basin, during the first quarter of 2020, we completed the 200 MMcf/d expansion of our processing capacity at our Bucking Horse facility, which increased our processing capacity to 345 MMcf/d. In addition, we placed in-service two compressor stations with 18,750 horsepower and significantly expanded the gas gathering system to connect numerous wells that had been drilled and completed by our producer customers.

Delaware Permian. In the Delaware Permian, through our Crestwood Permian joint venture, we are expanding our gas gathering systems and continue to optimize processing volumes at our Orla processing plant. Additionally, in the second quarter of 2020, we completed construction and commenced operations of a produced water gathering and salt water disposal system pursuant to an agreement with a large integrated producer in Culberson and Reeves Counties, Texas. The system capacity is 60 MBbls/d as of June 30, 2020 with plans to expand up to 120 MBbls/d based on producer activity.

Marketing, Supply and Logistics. In April 2020, we acquired several NGL storage and rail-to-truck LPG terminals from Plains for approximately $162 million. These assets are complementary to our existing NGL assets, are located in high demand markets across the central and eastern United States and include 7 MMBbls of NGL storage and seven LPG terminals. As a result of the acquisition, we now have approximately 10 MMBbls of NGL and LPG storage capacity and 13 LPG terminals offering expanded propane and butane services to the market, as well as greater access to a wide range of NGL and LPG supplies from hubs, pipelines, refiners and processors.

Regulatory Matters

Our regulatory matters are discussed in our 2019 Annual Report on Form 10-K and there have been no material changes in those matters from December 31, 2019 to June 30, 2020.

Critical Accounting Estimates

Our critical accounting estimates are consistent with those described in our 2019 Annual Report on Form 10-K. Below is an update of our critical accounting estimates related to goodwill, long-lived assets and equity method investments.

Goodwill

Our goodwill represents the excess of the amount we paid for a business over the fair value of the net identifiable assets acquired. We evaluate goodwill for impairment annually on December 31, and whenever events indicate that it is more likely than not that the fair value of a reporting unit could be less than its carrying amount. This evaluation requires us to compare the fair value of each of our reporting units to its carrying value (including goodwill). If the fair value exceeds the carrying amount, goodwill of the reporting unit is not considered impaired.

We estimate the fair value of our reporting units based on a number of factors, including discount rates, projected cash flows and the potential value we would receive if we sold the reporting unit. Estimating projected cash flows requires us to make certain assumptions as it relates to the future operating performance of each of our reporting units (which includes assumptions, among others, about estimating future operating margins and related future growth in those margins, contracting efforts and the cost and timing of facility expansions) and assumptions related to our customers, such as their future capital and operating plans and their financial condition. When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. If the assumptions embodied in the projections prove inaccurate, we could incur a future impairment charge. In addition, the use of the income approach to determine the fair value of our reporting units (see further discussion of the use of the income approach below) could result in a different fair value if we had utilized a market approach, or a combination thereof.

50

The following table summarizes the goodwill of our various reporting units (in millions):

			Impairment during the six months ended
	December 31, 2019		June 30,  2020		June 30, 2020
Gathering and Processing
Arrow	$	45.9	$	—	$	45.9
Powder River Basin	80.3		80.3		—
Marketing, Supply and Logistics
NGL Marketing and Logistics	92.7		—		92.7
Total	$	218.9	$	80.3	$	138.6

During the first quarter of 2020, current and forward commodity prices significantly declined from their levels at December 31, 2019 due primarily to the decreases in energy demand as a result of the outbreak of the COVID-19 pandemic and actions taken by the OPEC, Russia, the United States and other oil-producing countries relating to the oversupply of oil. We currently anticipate that the decrease in commodity prices will have a negative impact on certain of our customers in our gathering and processing segment, which could adversely impact the financial performance of certain of the reporting units within those operations.

Upon acquisition, we are required to record the assets, liabilities and goodwill of a reporting unit at its fair value on the date of acquisition. As a result, any level of decrease in the forecasted cash flows of these businesses or increases in the discount rates utilized to value those businesses from their respective acquisition dates would likely result in the fair value of the reporting unit falling below the carrying value of the reporting unit, and could result in an assessment of whether that reporting unit's goodwill is impaired.

We acquired our Powder River Basin reporting unit in 2019 and recorded it at fair value at that time. Based on the events that occurred during the first quarter of 2020 described above, we determined that the forecasted cash flows, and therefore the fair value of our Powder River Basin reporting unit significantly decreased during the first quarter of 2020, and accordingly performed a quantitative impairment assessment of the goodwill related to that reporting unit during that period. Based on our quantitative assessment, which utilized the income approach, we determined that the goodwill associated with the Powder River Basin reporting unit should be fully impaired during the first quarter of 2020, and accordingly recorded an $80.3 million impairment of the goodwill attributed to that reporting unit during the first quarter of 2020.

We continue to monitor our goodwill associated with our Arrow and NGL Marketing and Logistics reporting units, and if we receive additional negative information about market conditions or the intent of our customers to further curtail production, it could negatively impact the forecasted cash flows or discount rates utilized to determine the fair value of those businesses. A 40% decrease in the forecasted cash flows related to our Arrow and NGL Marketing and Logistics reporting units would not have resulted in an impairment of either of these reporting units. A 5% increase in the discount rate utilized to determine the fair value of our Arrow and NGL Marketing and Logistics reporting units at December 31, 2019 would also not have resulted in an impairment of either of these reporting units. There were no triggers which required us to evaluate our goodwill for impairment during the three months ended June 30, 2020.

Long-Lived Assets

Our long-lived assets consist of property, plant and equipment and intangible assets that have been obtained through multiple business combinations and property, plant and equipment that has been constructed in recent years. We continually monitor our business, the business environment and the performance of our operations to determine if an event has occurred that indicates that a long-lived asset may be impaired. If an event occurs, which is a determination that involves judgment, we may be required to utilize cash flow projections to assess our ability to recover the carrying value of our assets based on our long-lived assets’ ability to generate future cash flows on an undiscounted basis.

Projected cash flows of our long-lived assets are generally based on current and anticipated future market conditions, which require significant judgments to make projections and assumptions about pricing, demand, competition, operating costs, construction costs, legal and regulatory issues and other factors that may extend many years into the future and are often outside of our control. If those cash flow projections indicate that the long-lived asset’s carrying value is not recoverable, we record an

51

impairment charge for the excess of the carrying value of the asset over its fair value. The estimate of fair value considers a number of factors, including the potential value we would receive if we sold the asset, discount rates and projected cash flows. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates.

During the first quarter of 2020, current and forward commodity prices significantly declined from their levels at December 31, 2019 due primarily to the decreases in energy demand as a result of the outbreak of the COVID-19 pandemic and actions taken by the OPEC, Russia, the United States and other oil-producing countries relating to the oversupply of oil. We currently anticipate that the decrease in commodity prices could have a negative impact on certain of our customers in our gathering and processing segment, which could adversely impact the financial performance of certain of the reporting units within those operations. Although we currently anticipate that the decline in commodity prices have not decreased the forecasted financial performance of our operations to where the undiscounted cash flows to be generated by our long-lived asset groups have fallen below the carrying value of those long-lived asset groups, we continue to monitor our long-lived assets, and we could experience impairments of the carrying value of our long-lived assets in the future if we receive additional negative information about market conditions or the intent of our long-lived assets’ customers, which could negatively impact the forecasted cash flows utilized to determine the recoverability of those assets.

As noted above, during the first quarter of 2020, we recorded an impairment of the goodwill associated with our Powder River Basin reporting unit. The impairment of goodwill is different than our evaluation of the potential impairment of the long-lived assets of a reporting unit, because when we perform an assessment of the recoverability of goodwill, we utilize fair value estimates that primarily utilize discounted cash flows in the estimation process (as described above), and accordingly a reporting unit that has experienced a goodwill impairment may not experience a similar impairment of the underlying long-lived assets included in that reporting unit. Furthermore, a 40% decrease in the forecasted cash flows of our Powder River Basin reporting unit would not have resulted in a long-lived asset impairment. As a result, we did not record any material impairments of our property, plant and equipment and intangible assets during the first quarter of 2020. There were no triggers which required us to evaluate our long-lived assets for impairment during the three months ended June 30, 2020.

Equity Method Investments

We evaluate our equity method investments for impairment when events or circumstances indicate that the carrying value of the equity method investment may be impaired and that impairment is other than temporary. If an event occurs, we evaluate the recoverability of our carrying value based on the fair value of the investment. If an impairment is indicated, we adjust the carrying values of the asset downward, if necessary, to their estimated fair values.

We estimate the fair value of our equity method investments based on a number of factors, including discount rates, projected cash flows, enterprise value and the potential value we would receive if we sold the equity method investment. Estimating projected cash flows requires us to make certain assumptions as it relates to the future operating performance of each of our equity method investments (which includes assumptions, among others, about estimating future operating margins and related future growth in those margins, contracting efforts and the cost and timing of facility expansions) and assumptions related to our equity method investments’ customers, such as their future capital and operating plans and their financial condition. When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates.

During the first quarter of 2020, current and forward commodity prices significantly declined from their levels at December 31, 2019 due primarily to the decreases in energy demand as a result of the outbreak of the COVID-19 pandemic and actions taken by the OPEC, Russia, the United States and other oil-producing countries relating to the over supply of oil. We currently anticipate that the decrease in commodity prices could have a negative impact on certain of the customers of our equity-method investments, which could adversely impact the financial performance of certain of those investments. Although we currently anticipate that the decline in commodity prices has not decreased the fair value of our equity investments below their carrying value and any such decline would not be considered other than temporary, we continue to monitor our equity method investments (especially those with gathering and processing operations such as our Crestwood Permian equity method investment). If we receive additional negative information about market conditions or the intent of our equity method investments’ customers to curtail production in the future that negatively impacts the forecasted cash flows or discount rates utilized to determine the fair value of those investments, we could experience impairments to the carrying value of these investments.

Our equity method investments have long-lived assets, intangible assets, goodwill and equity method investments in their underlying financial statements, and our equity investees apply similar accounting policies and have similar critical accounting estimates in assessing those assets for impairment as we do. During the first quarter of 2020, we recorded a $4.5 million

52

reduction to the equity earnings from our PRBIC equity method investment as a result of us recording our proportionate share of a long-lived asset impairment recorded by the equity method investment. The carrying value of our PRBIC equity method investment was $3.8 million at June 30, 2020. None of our other equity method investments recorded any material impairments during the three and six months ended June 30, 2020.

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 interest and debt expense, 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 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 other transactions identified in a specific reporting period. The change in fair value of commodity inventory-related derivative contracts is considered in determining Adjusted EBITDA given that the timing of recognizing gains and losses on these derivative contracts differs from the recognition of revenue for the related underlying sale of inventory to which these derivatives relate. Changes in the fair value of other derivative contracts is not considered in determining Adjusted EBITDA given the relatively short-term nature of those derivative contracts. EBITDA and Adjusted EBITDA are not measures calculated in accordance with GAAP, as they do not include deductions for items such as depreciation, amortization and accretion, interest and income taxes, which are necessary to maintain our business. EBITDA and Adjusted EBITDA should not be considered as alternatives to net income, operating cash flow or any other measure of financial performance presented in accordance with GAAP. EBITDA and Adjusted EBITDA calculations may vary among entities, so our computation may not be comparable to measures used by other companies.

See our reconciliation of net income to EBITDA and Adjusted EBITDA in Results of Operations below.

53

Results of Operations

The following tables summarize our results of operations for the three and six months ended June 30, 2020 and 2019 (in millions):

	Crestwood Equity												Crestwood Midstream
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2020			2019			2020			2019			2020			2019			2020			2019
Revenues	$	352.7		$	683.4		$	1,080.6		$	1,518.6		$	352.7		$	683.4		$	1,080.6		$	1,518.6
Costs of product/services sold	225.7			537.2			760.1			1,232.8			225.7			537.2			760.1			1,232.8
Operations and maintenance expense	31.6			34.7			69.2			63.3			31.6			34.7			69.2			63.3
General and administrative expense	29.5			22.3			44.4			59.5			28.4			20.9			41.9			56.9
Depreciation, amortization and accretion	61.0			49.3			117.1			89.1			64.6			52.7			124.2			96.1
Loss on long-lived assets, net	3.8			—			4.8			2.0			3.8			—			4.8			2.0
Gain on acquisition	—			209.4			—			209.4			—			209.4			—			209.4
Goodwill impairment	—			—			80.3			—			—			—			80.3			—
Operating income (loss)	1.1			249.3			4.7			281.3			(1.4		)	247.3			0.1			276.9
Earnings from unconsolidated affiliates, net	8.4			3.7			13.9			10.6			8.4			3.7			13.9			10.6
Interest and debt expense, net	(34.0		)	(27.8		)	(66.6		)	(52.7		)	(34.0		)	(27.8		)	(66.6		)	(52.7		)
Other income, net	0.1			0.1			0.2			0.2			—			—			—			—
(Provision) benefit for income taxes	0.1			(0.3		)	0.1			(0.3		)	0.2			(0.3		)	0.2			(0.3		)
Net income (loss)	(24.3		)	225.0			(47.7		)	239.1			(26.8		)	222.9			(52.4		)	234.5
Add:
Interest and debt expense, net	34.0			27.8			66.6			52.7			34.0			27.8			66.6			52.7
Provision (benefit) for income taxes	(0.1		)	0.3			(0.1		)	0.3			(0.2		)	0.3			(0.2		)	0.3
Depreciation, amortization and accretion	61.0			49.3			117.1			89.1			64.6			52.7			124.2			96.1
EBITDA	70.6			302.4			135.9			381.2			71.6			303.7			138.2			383.6
Unit-based compensation charges	13.6			11.3			9.2			28.6			13.6			11.3			9.2			28.6
Loss on long-lived assets, net	3.8			—			4.8			2.0			3.8			—			4.8			2.0
Gain on acquisition	—			(209.4		)	—			(209.4		)	—			(209.4		)	—			(209.4		)
Goodwill impairment	—			—			80.3			—			—			—			80.3			—
Earnings from unconsolidated affiliates, net	(8.4		)	(3.7		)	(13.9		)	(10.6		)	(8.4		)	(3.7		)	(13.9		)	(10.6		)
Adjusted EBITDA from unconsolidated affiliates, net	17.9			14.0			37.2			33.6			17.9			14.0			37.2			33.6
Change in fair value of commodity inventory-related derivative contracts	21.5			3.7			15.7			4.8			21.5			3.7			15.7			4.8
Significant transaction and environmental related costs and other items	8.8			3.0			10.0			6.4			8.8			3.0			10.0			6.4
Adjusted EBITDA	$	127.8		$	121.3		$	279.2		$	236.6		$	128.8		$	122.6		$	281.5		$	239.0

54

	Crestwood Equity												Crestwood Midstream
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2020			2019			2020			2019			2020			2019			2020			2019
Net cash provided by operating activities	$	64.2		$	63.0		$	183.4		$	193.9		$	65.3		$	64.2		$	181.1		$	195.1
Net changes in operating assets and liabilities	(7.7		)	17.8			(11.4		)	(35.0		)	(7.7		)	18.0			(6.5		)	(33.9		)
Amortization of debt-related deferred costs	(1.6		)	(1.5		)	(3.2		)	(2.9		)	(1.6		)	(1.5		)	(3.2		)	(2.9		)
Interest and debt expense, net	34.0			27.8			66.6			52.7			34.0			27.8			66.6			52.7
Unit-based compensation charges	(13.6		)	(11.3		)	(9.2		)	(28.6		)	(13.6		)	(11.3		)	(9.2		)	(28.6		)
Loss on long-lived assets, net	(3.8		)	—			(4.8		)	(2.0		)	(3.8		)	—			(4.8		)	(2.0		)
Gain on acquisition	—			209.4			—			209.4			—			209.4			—			209.4
Goodwill impairment	—			—			(80.3		)	—			—			—			(80.3		)	—
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	(0.9		)	(3.0		)	(5.4		)	(6.3		)	(0.9		)	(3.0		)	(5.4		)	(6.3		)
Deferred income taxes	0.1			(0.1		)	0.3			(0.3		)	0.1			(0.2		)	0.1			(0.2		)
Provision (benefit) for income taxes	(0.1		)	0.3			(0.1		)	0.3			(0.2		)	0.3			(0.2		)	0.3
EBITDA	70.6			302.4			135.9			381.2			71.6			303.7			138.2			383.6
Unit-based compensation charges	13.6			11.3			9.2			28.6			13.6			11.3			9.2			28.6
Loss on long-lived assets, net	3.8			—			4.8			2.0			3.8			—			4.8			2.0
Gain on acquisition	—			(209.4		)	—			(209.4		)	—			(209.4		)	—			(209.4		)
Goodwill impairment	—			—			80.3			—			—			—			80.3			—
Earnings from unconsolidated affiliates, net	(8.4		)	(3.7		)	(13.9		)	(10.6		)	(8.4		)	(3.7		)	(13.9		)	(10.6		)
Adjusted EBITDA from unconsolidated affiliates, net	17.9			14.0			37.2			33.6			17.9			14.0			37.2			33.6
Change in fair value of commodity inventory-related derivative contracts	21.5			3.7			15.7			4.8			21.5			3.7			15.7			4.8
Significant transaction and environmental related costs and other items	8.8			3.0			10.0			6.4			8.8			3.0			10.0			6.4
Adjusted EBITDA	$	127.8		$	121.3		$	279.2		$	236.6		$	128.8		$	122.6		$	281.5		$	239.0

Segment Results

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

	Three Months Ended								Three Months Ended
	June 30, 2020								June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics
Revenues	$	114.5		$	3.1	$	235.1		$	199.7		$	4.9	$	478.8
Intersegment revenues	14.3			2.4		(16.7		)	25.4			3.2		(28.6		)
Costs of product/services sold	21.3			0.1		204.3			108.9			—		428.3
Operations and maintenance expenses	19.3			0.7		11.6			24.6			0.9		9.2
Loss on long-lived assets, net	(3.6		)	—		(0.2		)	(0.2		)	—		—
Gain on acquisition	—			—		—			209.4			—		—
Earnings (loss) from unconsolidated affiliates, net	(1.0		)	9.4		—			(2.8		)	6.5		—
EBITDA	$	83.6		$	14.1	$	2.3		$	298.0		$	13.7	$	12.7

55

	Six Months Ended								Six Months Ended
	June 30, 2020								June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics
Revenues	$	329.4		$	6.6	$	744.6		$	382.0		$	12.7	$	1,123.9
Intersegment revenues	54.3			5.0		(59.3		)	78.2			6.8		(85.0		)
Costs of product/services sold	129.6			0.3		630.2			246.9			—		985.9
Operations and maintenance expenses	46.3			2.1		20.8			42.7			1.9		18.7
Loss on long-lived assets, net	(4.6		)	—		(0.2		)	(2.0		)	—		(0.2		)
Goodwill impairment	(80.3		)	—		—			—			—		—
Gain on acquisition	—			—		—			209.4			—		—
Earnings (loss) from unconsolidated affiliates, net	(0.2		)	14.1		—			(3.0		)	13.6		—
EBITDA	$	122.7		$	23.3	$	34.1		$	375.0		$	31.2	$	34.1

Below is a discussion of the factors that impacted EBITDA by segment for the three and six months ended June 30, 2020 compared to the same periods in 2019.

Gathering and Processing

EBITDA for our gathering and processing segment decreased by approximately $214.4 million and $252.3 million during the three and six months ended June 30, 2020 compared to the same periods in 2019. The comparability of our gathering and processing segment’s EBITDA during the six months ended June 30, 2020 was impacted by an $80.3 million goodwill impairment related to our Jackalope operations. In addition, our gathering and processing segment’s EBITDA for the three and six months ended June 30, 2019 was impacted by a $209.4 million gain related to the acquisition of the remaining 50% equity interest in Jackalope. For a further discussion of these transactions, see “Critical Accounting Estimates” above and Item 1. Financial Statements, Notes 2 and 3.

Our gathering and processing segment’s revenues decreased by approximately $96.3 million and $76.5 million during the three and six months ended June 30, 2020 compared to the same periods in 2019, while our costs of product/services sold decreased by approximately $87.6 million and $117.3 million during those same periods. These decreases were primarily due to declines in commodity prices experienced during 2020 compared to 2019, which impacted the average prices that our gathering and processing segment realized on its agreements under which it purchases and sells crude oil and natural gas during the three and six months ended June 30, 2020 compared to the same periods in 2019.

During the three months ended June 30, 2020, our revenues decreased more than our costs of product/services sold as a result of the producer customers in the oil-weighted basins in which we operate deciding to electively shut-in production due to recent declines in commodity prices and resulting market conditions. During the three months ended June 30, 2020, natural gas, crude oil and water volumes gathered by our Arrow system decreased by 24%, 33%, and 18%, respectively, compared to the three months ended March 31, 2020. In addition, during the three months ended June 30, 2020, natural gas volumes gathered and processed by our Jackalope system decreased by 41% and 38% compared to the three months ended March 31, 2020. We anticipate that many of our gathering and processing segment’s producer customers will bring a portion of the shut-in production back online during the third quarter of 2020, and certain customers began the process of bringing shut-in production back online in late second quarter of 2020.

During the six months ended June 30, 2020, our costs of product/services sold decreased faster than our revenues primarily as a result of Arrow placing in service a 120 MMcf/d cryogenic plant in August 2019, which resulted in a 196%, 36%, 19% and 36% increase in natural gas processing volumes and natural gas, crude oil and water gathering volumes during the six months ended June 30, 2020 compared to the six months ended June 30, 2019. In addition, in April 2019, Crestwood Niobrara acquired the remaining 50% equity interest in Jackalope from Williams and we began consolidating Jackalope’s results, which partially offset the decrease in revenues experienced related to the decline in commodity prices and producer shut-ins described above.

Our gathering and processing segment’s operations and maintenance expenses decreased by approximately $5.3 million during the three months ended June 30, 2020 compared to the same period in 2019, primarily due to our cost cutting efforts which began in early second quarter 2020 as a result of the low commodity price environment discussed above. During the six

56

months ended June 30, 2020, our gathering and processing segment’s operations and maintenance expenses increased by approximately $3.6 million compared to the same period in 2019, primarily due to the acquisition of the remaining 50% equity interest in Jackalope in April 2019 as well as placing into service the Bear Den and Bucking Horse processing plants into service during 2019 and early 2020.

Our gathering and processing segment’s EBITDA for the three and six months ended June 30, 2020 was also impacted by a loss on long-lived assets of approximately $3.6 million and $4.6 million, primarily related to the retirement of certain water gathering lines on our Arrow system. During the six months ended June 30, 2019, we recorded a loss on long-lived assets of approximately $2.0 million, primarily related to the retirement and disposal of our Granite Wash gathering and processing assets.

Our gathering and processing segment’s EBITDA was also impacted by an increase in earnings from unconsolidated affiliates of approximately $1.8 million and $2.8 million during the three and six months ended June 30, 2020 compared to the same periods in 2019. During the three and six months ended June 30, 2020, we recorded an equity loss of approximately $1.0 million and $0.2 million related to our Crestwood Permian equity investment. During the three months ended June 30, 2020, Crestwood Permian’s revenues and costs of products sold decreased compared to the three months ended March 31, 2020 as its gathering and processing volumes from its Orla and Willow Lake gathering and processing systems decreased by 35% and 26%, respectively, as a result of its producer customers shutting in production in response to the recent decline in commodity prices. Crestwood Permian’s major customer in the Delaware Permian began bringing shut-in production back online in late June 2020. During the three and six months ended June 30, 2019, we recorded an equity loss of approximately $3.3 million and $6.7 million related to our Crestwood Permian equity investment. During the first half of 2019, Crestwood Permian experienced lower average margin on certain of its gathering contracts due to higher transportation and fractionation fees resulting in lower revenues. In addition, Crestwood Permian recorded a loss on the retirement of certain of its gathering and processing assets during the three and six months ended June 30, 2019. Equity earnings from our Jackalope equity investment decreased by approximately $0.5 million and $3.7 million during the three and six months ended June 30, 2020 compared to the same periods in 2019, due to the acquisition of the remaining 50% equity interest in Jackalope from Williams in April 2019.

Storage and Transportation

EBITDA for our storage and transportation segment increased by $0.4 million during the three months ended June 30, 2020 compared to the same period in 2019, while we experienced a decrease in EBITDA of approximately $7.9 million during the six months ended June 30, 2020 compared to the same period in 2019. Revenues from our COLT Hub operations decreased by approximately $2.6 million and $7.9 million during the three and six months ended June 30, 2020 compared to the same periods in 2019. The decrease in revenues from our COLT Hub operations during the three and six months ended June 30, 2020 compared to the same periods in 2019 was primarily due to the decline in demand for rail loading services which resulted in a decrease of 33% and 15%, respectively, in rail loading volumes during those periods. During the six months ended June 30, 2019, we recognized approximately $4.9 million of revenues under a take-or-pay contract with one of our rail loading customers which expired in 2019. In addition, in late 2019 and early 2020, we renewed several rail loading and storage contracts at lower rates resulting in lower revenues during the six months ended June 30, 2020 compared to the same period in 2019.

Our storage and transportation segment’s costs of product/services sold and operations and maintenance expenses were relatively flat during the three and six months ended June 30, 2020 compared to the same periods in 2019.

Our storage and transportation segment’s EBITDA was also impacted by a net increase in earnings from unconsolidated affiliates during the three and six months ended June 30, 2020 compared to the same periods in 2019. Earnings from our Stagecoach Gas equity investment increased by approximately $2.8 million and $5.0 million during the three and six months ended June 30, 2020 compared to the same periods in 2019, primarily due to our share of its equity earnings increasing from 40% to 50% effective July 1, 2019. Aside from this change in earnings percentage, our earnings from our Stagecoach Gas equity investment were relatively flat. This was due to demand for the natural gas storage and transportation services provided by Stagecoach Gas being relatively flat given that the Northeast market for natural gas in which Stagecoach Gas operates is experiencing declining natural gas prices and basis differentials, offset by an increase in producer activity and lack of new infrastructure being built, which is keeping the demand for Stagecoach Gas’s storage and transportation services relatively stable. Earnings from our PRBIC equity investment decreased by approximately $4.3 million during the six months ended June 30, 2020 compared to the same period in 2019. During the first quarter of 2020, we recorded a $4.5 million reduction in equity earnings from PRBIC to reflect our proportionate share of a long-lived asset impairment recorded by our PRBIC equity investment.

57

Marketing, Supply and Logistics

EBITDA for our marketing, supply and logistics segment decreased by approximately $10.4 million during the three months ended June 30, 2020 compared to the same period in 2019, while our EBITBA for the six months ended June 30, 2020 was flat compared to the same period in 2019. Our marketing supply and logistics segment’s revenues decreased by approximately $231.8 million and $353.6 million during the three and six months ended June 30, 2020, while our costs of product/services sold decreased by approximately $224.0 million and $355.7 million during those same periods.

Our crude and natural gas marketing operations experienced a decrease in its revenues of approximately $190.1 million and $229.1 million during the three and six months ended June 30, 2020 compared to the same periods in 2019, and a decrease in its products costs of approximately $188.9 million and $225.5 million during those same periods. These decreases were driven by lower average sales prices to our customers due to lower commodity prices, partially offset by higher crude marketing volumes due to increased marketing activity surrounding our crude-related operations as a result of greater volatility in crude prices experienced during the three and six months ended June 30, 2020.

Our NGL marketing and logistics operations experienced a reduction in revenues of approximately $41.7 million and $124.5 million during the three and six months ended June 30, 2020 compared to the same periods in 2019, and a decrease in its costs of product/services sold of approximately $35.1 million and $130.2 million during those same periods. These decreases were primarily driven by declining NGL prices. During the first half of 2020, NGL prices decreased due to a combination of decreases in overall commodity prices, high NGL production and constrained NGL infrastructure. Our NGL marketing and logistics operations’ costs of product/services sold decreased more than its revenues during the six months ended June 30, 2020 due to an increase in our NGL marketing activity, as we continued to take advantage of market disruptions and low NGL prices to create strong margin for delivery into forward markets, and the constrained NGL infrastructure increased demand for our storage, terminalling and transportation assets. Included in our costs of product/services sold was a gain of $6.8 million and $28.8 million during the three and six months ended June 30, 2020, and a gain of $9.9 million and $7.0 million during the three and six months ended June 30, 2019 related to our price risk management activities.

Our marketing, supply and logistics operations and maintenance expenses increased by approximately $2.4 million and $2.1 million during the three and six months ended June 30, 2020 compared to the same periods in 2019, primarily due to the acquisition of several NGL storage and rail-to-truck LPG terminals from Plains in April 2020.

Other EBITDA Results

General and Administrative Expenses. During the three months ended June 30, 2020, our general and administrative expenses increased by approximately $7 million compared to the same period in 2019, primarily due to costs related to restructuring our operations in response to the recent decline in commodity prices. During the six months ended June 30, 2020, our general and administrative expenses decreased by approximately $15 million compared to the same period in 2019. During the six months ended June 30, 2020, we were allocated less unit-based compensation charges from Crestwood Holdings as a result of the impact of the decrease in the market price for Crestwood Equity’s common units.

Items not affecting EBITDA include the following:

Depreciation, Amortization and Accretion Expense. During the three and six months ended June 30, 2020, our depreciation, amortization and accretion expensed increased by approximately $12 million and $28 million compared to the same periods in 2019, primarily due to the acquisition of the remaining 50% equity interest in Jackalope in April 2019 and the acquisition of NGL storage and terminalling assets from Plains in April 2020. In addition, we placed in-service the expansion of our processing capacity at our Bucking Horse processing facility in the first quarter of 2020 and placed into service the Bear Den II processing plant on our Arrow system in late 2019.

Interest and Debt Expense, Net. Interest and debt expense, net increased by approximately $6.2 million and $13.9 million during the three and six months ended June 30, 2020 compared to the same periods in 2019, primarily due to the issuance of $600 million unsecured senior notes due 2027 in April 2019. In addition, our capitalized interest was higher during the three and six months ended June 30, 2019, compared to the same periods in 2020 due to the timing of growth capital projects primarily in the Bakken and Powder River Basin.

58

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2020		2019		2020		2019
Credit facility	$	6.1	$	5.7	$	12.5	$	13.6
Senior notes	26.5		25.2		53.1		43.3
Other debt-related costs	1.8		1.6		3.6		3.2
Gross interest and debt expense	34.4		32.5		69.2		60.1
Less: capitalized interest	0.4		4.7		2.6		7.4
Interest and debt expense, net	$	34.0	$	27.8	$	66.6	$	52.7

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 credit facility, and sales of equity and debt securities. Our equity investments use cash from their respective operations to fund their operating activities, maintenance and growth capital expenditures, and service their outstanding indebtedness.

The COVID-19 pandemic’s impact on global crude oil demand and corresponding supply and demand imbalances have created significant near-term challenges for the energy industry including record low commodity prices, production declines and temporary shut-ins for producers in every major basin across North America. We are aggressively responding to these extraordinary market events by canceling or delaying capital projects, substantially reducing operating and administrative costs, optimizing our storage assets and working closely with our customers to maintain volumes across our diversified asset portfolio. Through these steps, combined with the steps we have taken over the past few years, 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 $9 million to Crestwood Niobrara’s non-controlling partner. We believe our operating cash flows will exceed cash distributions to our partners, preferred unitholders and non-controlling partner, and as a result, we will have adequate operating cash flows as a source of liquidity for our growth capital expenditures.

On July 16, 2020, we declared a quarterly cash distribution of $0.625 per unit to our common unitholders, which will be paid on August 14, 2020 and was consistent with the distribution paid in May 2020. Based on the impact that the recent decline in commodity prices has had and could continue to have on our customers and our financial performance in future quarters, our Board of Directors will be evaluating the level of distributions to our common and preferred unitholders. The Board of Directors will consider a wide range of strategic, commercial, operational and financial factors, including current and projected operating cash flows and liquidity needs and the potential adverse impact of future distribution reductions on our common unitholders, including our general partner. The evaluation will also include a review of the potential for an event of default of the debt of Crestwood Holdings, which could result in a change in control at Crestwood Holdings and, accordingly, in us, which is further described in Part II, Item 1A. Risk Factors.

As of June 30, 2020, we had $424.9 million of available capacity under the Crestwood Midstream credit facility considering the most restrictive debt covenants in the credit agreement. As of June 30, 2020, we were in compliance with all of our debt covenants applicable to the credit facility and senior notes. 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.

59

Cash Flows

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

	Six Months Ended
	June 30,
	2020			2019
Net cash provided by operating activities	$	183.4		$	193.9
Net cash used in investing activities	$	(292.9	)	$	(684.0	)
Net cash provided by financing activities	$	90.5		$	475.0

Operating Activities

Our operating cash flows decreased by approximately $10.5 million during the six months ended June 30, 2020 compared to the same period in 2019. During the six months ended June 30, 2020, our operating revenues decreased by approximately $438.0 million, while our costs of product services/sold decreased by approximately $472.7 million compared to the same period in 2019. These decreases were primarily driven by our marketing, supply and logistics segment’s and gathering and processing segment’s operations as discussed in Results of Operations above. We also experienced an increase in our operations and maintenance expenses of approximately $5.9 million during the six months ended June 30, 2020 compared to the same period in 2019, primarily due to the acquisition of the remaining 50% equity interest in Jackalope in April 2019 and the acquisition of NGL assets from Plains in April 2020. Our interest and debt expense, net increased by approximately $13.9 million during the six months ended June 30, 2020 compared to the same period in 2019 primarily due to the issuance of $600 million of senior notes in April 2019. In addition, the decrease in net operating cash flows was also impacted by a $23.6 million reduction in net cash inflow from working capital requirements, primarily from our marketing, supply and logistics operations.

Investing Activities

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

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

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

As a part of our strategic plan to address the current downturn in commodity prices, we have reduced our projection of growth capital expenditures to approximately $140 million to $160 million for 2020, and our projection of maintenance capital expenditures to approximately $10 million to $15 million and reimbursable capital expenditures to $15 million and $25 million, respectively for 2020. Our growth capital expenditures for the remainder of the year will be primarily focused on completing in-progress water and gas gathering and processing projects and well connections. 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. The following table summarizes our capital expenditures for the six months ended June 30, 2020 (in millions):

Growth capital	$	127.2
Maintenance capital	6.4
Other (1)	9.6
Purchases of property, plant and equipment	$	143.2

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

Acquisitions. In April 2020, we acquired several NGL storage and rail-to-truck LPG terminals from Plains for approximately $162 million. In April 2019, Crestwood Niobrara acquired the remaining 50% equity interest in Jackalope from Williams for approximately $462 million, net of cash acquired. For a further discussion of these acquisitions, see Item 1. Financial Statements, Note 3.

60

Investments in Unconsolidated Affiliates. During the six months ended June 30, 2020 and 2019, we contributed approximately $6.0 million and $6.5 million to our Tres Palacios and PRBIC equity investments for their operating purposes. During the six months ended June 30, 2019, we contributed approximately $10.0 million to our Crestwood Permian equity investment primarily to fund its expansion projects and also contributed $24.4 million to our Jackalope equity investment prior to our acquisition of the remaining 50% equity interest in Jackalope from Williams, and this contribution was primarily utilized by us after Jackalope’s consolidation to fund its growth capital expenditures.

Financing Activities

The following equity and debt transactions impacted our financing activities during the six months ended June 30, 2020:

Equity and Debt Transactions

• During the six months ended June 30, 2020, distributions to our partners increased by $4.8 million compared to the same period in 2019, primarily due to the increase in our distribution per limited partner unit from $0.60 per limited partner unit to $0.625 per limited partner unit;

• During the six months ended June 30, 2020 and 2019, Crestwood Niobrara paid cash distributions of $18.5 million and $6.6 million to its non-controlling partner. In addition, during the six months ended June 30, 2020, Crestwood Niobrara received contributions of $2.8 million from its non-controlling partner;

• During the six months ended June 30, 2019, Crestwood Niobrara issued $235 million in new Series A-3 Preferred Units to Jackalope Holdings in conjunction with Crestwood Niobrara’s acquisition of the remaining 50% equity interest in Jackalope from Williams. For a further discussion of this transaction, see Item 1. Financial Statements, Note 10;

• During the six months ended June 30, 2020, our taxes paid from unit-based compensation vesting increased by $4.9 million compared to the same period in 2019, primarily due to higher vesting of unit-based compensation awards; and

• During the six months ended June 30, 2020, our debt-related transactions resulted in net proceeds of approximately $244.3 million compared to net proceeds of $375.5 million during the six months ended June 30, 2019.

61

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Our interest rate risk and commodity price, market and credit risks are discussed in our 2019 Annual Report on Form 10-K. There have been no material changes in those exposures from December 31, 2019 to June 30, 2020, other than as set forth below.

Credit Risk

Credit risk if the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing and controlling credit risk and have established control procedures, which are reviewed on an ongoing basis. We have diversified our credit risk through having long-term contracts with many investment grade customers and creditworthy procedures. Additionally, we perform credit analyses of our customers on a regular basis pursuant to our corporate credit policy. We have not had any significant losses due to failures to perform by counterparties.

In June 2020, Chesapeake, our major customer in the Powder River Basin, filed for protection under Chapter 11 of the U.S. Bankruptcy Code and in July 2020, Bruin, our major customer in the Bakken also filed for protection under Chapter 11 of the U.S. Bankruptcy Code. Although Chesapeake and Bruin were current on all amounts due to us as of June 30, 2020 and additional cash flow protection is in place with Chesapeake via letters of credit, we are closely monitoring our exposure to Chesapeake and Bruin to ensure they continue to promptly pay amounts invoiced to them.

Under a number of our customer contracts, there are provisions that provide for our right to request or demand credit assurances from our customers including the posting of letters of credit, surety bonds, cash margin or collateral held in escrow for varying levels of future revenues. We continue to closely monitor our producer customer base since a majority of our customers in our gathering and processing and storage and transportation operations are either not rated by the major rating agencies or had below investment grade credit ratings.

Item 4. Controls and Procedures

Disclosure Controls and Procedures

As of June 30, 2020, Crestwood Equity and Crestwood Midstream carried out an evaluation under the supervision and with the participation of their respective management, including the Chief Executive Officer and Chief Financial Officer of their General Partners, as to the effectiveness, design and operation of our disclosure controls and procedures (as defined in the Securities Exchange Act of 1934, as amended (Exchange Act) Rules 13a-15(e) and 15d-15(e)). Crestwood Equity and Crestwood Midstream maintain controls and procedures designed to provide reasonable assurance that information required to be disclosed in their respective reports that are filed or submitted under the Exchange Act of 1934, as amended, are recorded, processed, summarized and reported within the time periods specified by the rules and forms of the SEC, and that information is accumulated and communicated to their respective management, including the Chief Executive Officer and Chief Financial Officer of their General Partners, as appropriate, to allow timely decisions regarding required disclosure. Such management, including the Chief Executive Officer and Chief Financial Officer of their General Partners, do not expect that the disclosure controls and procedures or the internal controls will prevent and/or detect all errors and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Crestwood Equity’s and Crestwood Midstream’s disclosure controls and procedures are designed to provide reasonable assurance of achieving their objectives and our 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, 2020.

Changes in Internal Control over Financial Reporting

There were no changes to Crestwood Equity’s or Crestwood Midstream’s internal control over financial reporting during the three months ended June 30, 2020 that have materially affected, or are reasonably likely to materially affect Crestwood Equity’s or Crestwood Midstream’s internal control over financial reporting.

62

PART II – OTHER INFORMATION

Item 1. Legal Proceedings

Part I, Item 1. Financial Statements, Note 11 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 below or 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 2019 Annual Report on Form 10-K, as supplemented by the risk factors set forth below. There has been no material change in the risk factors set forth in our 2019 Annual Report on Form 10-K other than those set forth below.

Our gathering and processing operations depend, in part, on drilling and production decisions of others.

Our gathering and processing operations are dependent on the continued availability of natural gas and crude oil production. We have no control over the level of drilling activity in our areas of operation, the amount of reserves associated with wells connected to our systems, or the rate at which production from a well declines. Our gathering systems are connected to wells whose production will naturally decline over time, which means that our cash flows associated with these wells will decline over time. To maintain or increase throughput levels on our gathering systems and utilization rates at our natural gas processing plants, we must continually obtain new natural gas and crude oil supplies. Our ability to obtain additional sources of natural gas and crude oil primarily depends on the level of successful drilling activity near our systems, our ability to compete for volumes from successful new wells, and our ability to expand our system capacity as needed. If we are not able to obtain new supplies of natural gas and crude oil to replace the natural decline in volumes from existing wells, throughput on our gathering and processing facilities would decline, which could have a material adverse effect on our results of operations and distributable cash flow.

Although we have acreage dedications from customers that include certain producing and non-producing oil and gas properties, our customers are not contractually required to develop the reserves or properties they have dedicated to us. We have no control over producers or their drilling and production decisions in our areas of operations, which are affected by, among other things: (i) the availability and cost of capital; (ii) prevailing and projected commodity prices; (iii) demand for natural gas, NGLs and crude oil; (iv) levels of reserves and geological considerations; (v) governmental regulations, including the availability of drilling permits and the regulation of hydraulic fracturing; (vi) the availability of drilling rigs and other development services; (vii) fluctuations in energy prices that can greatly affect the development of oil and gas reserves; (viii) the availability of storage of crude oil and other commodities; and (ix) the impact of illness, pandemics or any other public health crisis, including the COVID-19 pandemic, could have on demand for commodities. Drilling and production activity generally decreases as commodity prices decrease (such as what could be experienced with the decline in commodity prices during the first half of 2020, as further described in “Our business depends on hydrocarbon supply and demand fundamentals, which can be adversely affected by numerous factors outside of our control” below), and sustained declines in commodity prices could lead to a material decrease in such activity. Because of these factors, even if oil and gas reserves are known to exist in areas served by our assets, producers may choose not to develop those reserves. For example, many of our customers have recently announced reductions in their estimated capital expenditures for 2020 and beyond. Reductions in exploration or production activity in our areas of operations could lead to reduced utilization of our systems.

Our business depends on hydrocarbon supply and demand fundamentals, which can be adversely affected by numerous factors outside of our control.

Our success depends on the supply and demand for natural gas, NGLs and crude oil, which has historically generated the need for new or expanded midstream infrastructure. The degree to which our business is impacted by changes in supply or demand varies. Our business can be negatively impacted by sustained downturns in supply and demand for one or more commodities, including reductions in our ability to renew contracts on favorable terms and to construct new infrastructure. For example, significantly lower commodity prices during the past few years have resulted in an industry-wide reduction in capital expenditures by producers and a slowdown in drilling, completion and supply development efforts. Notwithstanding this market downturn, production volumes of crude oil, natural gas and NGLs have continued to grow (or decline at a slower rate

63

than expected). Similarly, major factors that will impact natural gas demand domestically will be the realization of potential liquefied natural gas exports and demand growth within the power generation market. Factors expected to impact crude oil demand include production cuts and freezes implemented by OPEC members and other large oil producers such as Russia. For example, during the first quarter of 2020, OPEC and Russia failed to agree on a plan to cut production of oil and related commodities. Subsequently, Saudi Arabia announced plans to increase production and reduce the prices at which they sell oil. While OPEC, Russia, the United States and other oil and gas producing countries subsequently agreed to collectively decrease production, these events, combined with the outbreak of the COVID-19 pandemic that has reduced economic activity and the related demand for oil, have contributed to a sharp drop in prices for crude oil during the first half of 2020. The effect of these events on the price of oil was further exacerbated by a shortage in available storage for hydrocarbons in the United States, which caused the prices for oil to further decrease dramatically in May 2020. In addition, the supply and demand for natural gas, NGLs and crude oil for our business will depend on many other factors outside of our control, some of which include:

• changes in general domestic and global economic and political conditions;

• changes in domestic regulations that could impact the supply or demand for oil and gas;

• technological advancements that may drive further increases in production and reduction in costs of developing shale plays;

• competition from imported supplies and alternate fuels;

• commodity price changes, including the recent decline in crude oil and natural gas prices, that could negatively impact the supply of, or the demand for these products;

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

• the availability of hydrocarbon storage;

• increased costs to explore for, develop, produce, gather, process or transport commodities;

• impact of interest rates on economic activity;

• shareholder activism and activities by non-governmental organizations to limit sources of funding for the energy sector or restrict the exploration, development and production of oil and gas:

• operational hazards, including terrorism, cyber-attacks or domestic vandalism;

• adoption of various energy efficiency and conservation measures; and

• perceptions of customers on the availability and price volatility of our services, particularly customers’ perceptions on the volatility of commodity prices over the longer-term.

If volatility and seasonality in the oil and gas industry increase, because of increased production capacity, reduced demand for energy, or otherwise, the demand for our services and the fees that we will be able to charge for those services may decline. In addition to volatility and seasonality, an extended period of low commodity prices, as the industry is currently experiencing, could adversely impact storage and transportation values for some period of time until market conditions adjust. With West Texas Intermediate crude oil prices ranging from $66.24 to $46.31 per barrel in 2019 and from $63.27 to negative $36.98 per barrel in 2020, the sustainability of recent and longer-term oil prices cannot be predicted. These commodity price impacts could have a negative impact on our business, financial condition, and results of operations.

The widespread outbreak of an illness, pandemic (like COVID-19) or any other public health crisis may have material adverse effects on our business, financial position, results of operations and/or cash flows.

In December 2019, a novel strain of coronavirus (SARS-Cov-2), which causes COVID-19, was reported to have surfaced in China. The spread of this virus has caused business disruption, including disruption to the oil and natural gas industry. In March 2020, the World Health Organization declared the outbreak of COVID-19 to be a pandemic, and the U.S. economy began to experience pronounced effects. The COVID-19 pandemic has negatively impacted the global economy, disrupted global supply chains, reduced global demand for oil and gas, and created significant volatility and disruption of financial and commodity markets. The COVID-19 pandemic has also caused federal and local governments to implement measures to quarantine individuals and limit gatherings, which has impacted our workforce and the way we have traditionally conducted our business. If COVID-19 were to impact a location where we have a high concentration of business and resources, our local workforce could be affected by such an occurrence or outbreak which could also significantly disrupt our operations and decrease our ability to provide gathering, processing, storage and transportation services to our natural gas and crude oil customers. The extent of the impact of the COVID-19 pandemic on our operational and financial performance, including our ability to execute our business strategies and initiatives in the expected time frame, is uncertain and depends on various factors, including the demand for oil and natural gas (including the impact that reductions in travel, manufacturing and consumer product demand have had and will have on the demand for commodities), the availability of personnel, equipment and services critical to our ability to operate our assets and the impact of potential governmental restrictions on travel, transportation and operations. There is uncertainty around the extent and duration of the disruption. The degree to which the COVID-19 pandemic or any other public health crisis adversely impacts our results will depend on future developments, which are highly uncertain and cannot be predicted. These developments include, but are not limited to, the duration and spread of the outbreak,

64

its severity, the actions to contain the virus or treat its impact, its impact on the economy and market conditions, and how quickly and to what extent normal economic and operating conditions can resume. These potential impacts, while uncertain, could adversely affect our operating results.

A significant portion of our revenues is derived from our operations in the Bakken shale, and due to such geographic concentration, adverse developments in the Bakken could impact our financial condition and results of operations.

A significant portion of the our revenue is derived from our operations in the Bakken shale. These operations accounted for approximately 46% of our total revenues, less of costs of product/services sold, during the six months ended June 30, 2020. Due to this geographic concentration of our operations, adverse developments that affect customers, suppliers or operations in the Bakken, such as catastrophic events or weather, health pandemics, and changes in supply or demand of crude oil, natural gas and related commodities that impact regional commodity prices and availability of infrastructure, could have a significantly greater impact on our financial condition and results of operations than if we maintained operations in more diverse locations.

We are exposed to credit risks of our customers, and any material nonpayment or nonperformance by our key customers could adversely affect our cash flows and results of operations.

Many of our customers may experience financial problems that could have a significant effect on their creditworthiness. Severe financial problems encountered by our customers could limit our ability to collect amounts owed to us, or to enforce performance of obligations under contractual arrangements. In addition, many of our customers finance their activities through cash flows from operations, the incurrence of debt or the issuance of equity. The combination of the reduction of cash flows resulting from declines in commodity prices (such as experienced during the first half of 2020), a reduction in borrowing bases under a reserve-based credit facility and the lack of availability of debt or equity financing may result in a significant reduction of customers’ liquidity and limit their ability to make payments or perform on their obligations to us. Furthermore, some of our customers may be highly leveraged and subject to their own operating and regulatory risks, which increases the risk that they may default on their obligations to us. For example, in June 2020, Chesapeake, our major customer in the Powder River Basin, announced that they filed for protection under Chapter 11 of the U.S. Bankruptcy Code. Although Chesapeake is current on all amounts due to us and additional cash flow protection is in place via letters of credit, we are closely monitoring our exposure to Chesapeake to ensure they continue to promptly pay amounts invoiced to them. Financial problems experienced by our customers could result in the impairment of our assets, reduction of our operating cash flows and may also reduce or curtail their future use of our products and services, which could reduce our revenues.

Changes in future business conditions could cause recorded long-lived assets and goodwill to become further impaired, and our financial condition and results of operations could suffer if there is an additional impairment of long-lived assets and goodwill.

We continually monitor our business, the business environment and the performance of our operations to determine if an event has occurred that indicates that a long-lived asset may be impaired. If an event occurs, which is a determination that involves judgment, we may be required to utilize cash flow projections to assess our ability to recover the carrying value of our assets based on our long-lived assets’ ability to generate future cash flows on an undiscounted basis. This differs from our evaluation of goodwill, which is evaluated for impairment annually on December 31, and whenever events indicate that it is more likely than not that the fair value of a reporting unit could be less than the carrying amount. This evaluation requires us to compare the fair value of each of our reporting units primarily utilizing discounted cash flows, to its carrying value (including goodwill). If the fair value exceeds the carrying value amount, goodwill of the reporting unit is not considered impaired.

During the first quarter of 2020, we determined that the goodwill associated with our Powder River Basin reporting unit should be fully impaired, and accordingly recorded an $80.3 million impairment of its goodwill.

Our long-lived assets and goodwill impairment analyses are sensitive to changes in key assumptions used in our analysis, such as expected future cash flows, the degree of volatility in equity and debt markets and our unit price. If the assumptions used in our analysis are not realized, it is possible a material impairment charge may need to be recorded in the future. We cannot accurately predict the amount and timing of any impairment of long-lived assets or goodwill. Any additional impairment charges that we may take in the future could be material to our results of operations and financial condition. For a further discussion of our goodwill impairment, see Part I, Item 1. Financial Information, Note 2.

65

A change of control could result in us facing substantial repayment obligations under our revolving credit facility and indentures governing our senior notes.

Our credit agreement and indentures governing our senior notes contain provisions relating to change of control of Crestwood Equity’s general partner. If these provisions are triggered, our outstanding indebtedness may become due. For example, a change of control of Crestwood Equity’s general partner may occur if our parent, Crestwood Holdings, became unable to service its debt and an event of default occurred under the documents governing its debt. If our Board of Directors reduces the level of distributions to our common unitholders in future quarters as a consequence of the recent significant decline in commodity prices or for other reasons, the ability of our parent to service its debt may be adversely affected. In the event our outstanding indebtedness became due, there is no assurance that we would be able to pay the indebtedness, in which case the lenders under the revolving credit facility would have the right to foreclose on our assets and holders of our senior notes would be entitled to require us to repurchase all or a portion of our notes at a purchase price equal to 101% of the principal amount thereof, plus accrued and unpaid interest, if any, to the date of such repurchase, which would have a material adverse effect on us. There is no restriction on our ability or the ability of Crestwood Equity’s general partner or its parent companies to enter into a transaction which would trigger the change of control provision. In certain circumstances, the control of our general partner may be transferred to a third party without unitholder consent, and this may be considered a change in control under our revolving credit facility and senior notes. Please read “The control of our general partner may be transferred to a third party without unitholder consent” below.

The control of our general partner may be transferred to a third party without unitholder consent.

Our general partner may transfer its general partner interest to a third party in a merger or in a sale of all or substantially all of its assets without the consent of our unitholders. Furthermore, there is no restriction in our partnership agreement on the ability of the owner of our general partner, Crestwood Holdings LP, from transferring its ownership interest in our general partner to a third party. Additionally, Crestwood Holdings LP’s general partner interest in our general partner is pledged as collateral under a Credit Agreement between Crestwood Holdings and various lenders (Holdings Credit Agreement).  In the event of a default by Crestwood Holdings under the Holdings Credit Agreement, the lenders may foreclose on the pledged general partner interest and take or transfer control of our general partner without unitholder consent. The new owner of our general partner would then be in a position to replace the board of directors and officers of our general partner with its own choices and to control the decisions taken by our board of directors and officers. This effectively permits a “change of control” without the vote or consent of the common unitholders. In addition, such a change of control could result in our indebtedness becoming due.

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.

66

Item 6. Exhibits

Exhibit Number	Description
2.1	Contribution Agreement, dated as of April 20, 2016, by and between Crestwood Pipeline and Storage Northeast LLC and Con Edison Gas Pipeline and Storage Northeast, LLC (incorporated by reference to Exhibit 2.1 to Crestwood Equity Partners LP's Form 8-K filed on April 22, 2016)
2.2	Purchase Agreement, dated as of April 9, 2019, by and between Crestwood Niobrara LLC and Williams MLP Operating, LLC (incorporated by reference to Exhibit 2.1 to Crestwood Equity Partners LP’s Form 8-K filed on April 10, 2019)
3.1	Certificate of Limited Partnership of Inergy, L.P. (incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Registration Statement on Form S-1 filed on March 14, 2001)
3.2	Certificate of Correction of Certificate of Limited Partnership of Inergy, L.P. (incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Form 10-Q filed on May 12, 2003)
3.3	Amendment to the Certificate of Limited Partnership of Crestwood Equity Partners LP (the “Company”) (f/k/a Inergy, L.P.) dated as of October 7, 2013 (incorporated herein by reference to Exhibit 3.2 to Crestwood Equity Partners LP's Form 8-K filed on October 10, 2013)
3.4	Certificate of Formation of Inergy GP, LLC (incorporated by reference to Exhibit 3.5 to Inergy, L.P.'s Registration Statement on Form S-1/A filed on May 7, 2001)
3.5	Certificate of Amendment of Crestwood Equity GP LLC (the “General Partner”) (f/k/a Inergy GP, LLC) dated as of October 7, 2013 (incorporated by reference to Exhibit 3.3A to Crestwood Equity Partners LP's Form 10-Q filed on November 8, 2013)
3.6	First Amended and Restated Limited Liability Company Agreement of Inergy GP, LLC dated as of September 27, 2012 (incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Form 8-K filed on September 27, 2012)
3.7	Amendment No. 1 to the First Amended and Restated Limited Liability Company Agreement of the General Partner entered into and effective as of October 7, 2013 (incorporated by reference to Exhibit 3.4A to Crestwood Equity Partners LP's Form 10-Q filed on November 8, 2013)
3.8	Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP dated as of April 11, 2014 (incorporated herein by reference to Exhibit 3.1 to Crestwood Equity Partners LP's Form 8-K filed on April 11, 2014)
3.9	First Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of September 30, 2015 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partner LP’s Form 8-K filed on October 1, 2015)
3.10	Second Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of November 8, 2017 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partners LP’s Form 8-K filed on November 13, 2017)
3.11	Third Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of May 30, 2018 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partners LP’s Form 8-K filed on June 4, 2018)
3.12	Second Amended and Restated Agreement of Limited Partnership of Crestwood Midstream Partners LP, dated as of September 30, 2015 (incorporated by reference to Exhibit 3.1 to Crestwood Midstream Partners LP's Form 8-K filed on October 1, 2015)
3.13	Certificate of Formation of NRGM GP, LLC (incorporated herein by reference to Exhibit 3.7 to Inergy Midstream, L.P.'s Form S-1/A filed on November 21, 2011)
3.14	Amended and Restated Limited Liability Company Agreement of NRGM GP, LLC, dated December 21, 2011 (incorporated herein by reference to Exhibit 3.2 to Inergy Midstream, L.P.'s Form 8-K filed on December 22, 2011)
3.15	Amendment No. 1 to the Amended and Restated Limited Liability Company Agreement of Crestwood Midstream GP LLC (f/k/a NRGM GP, LLC) (incorporated herein by reference to Exhibit 3.39 to Crestwood Midstream Partners LP's Form S-4/A filed on October 28, 2013)
3.16	Fourth Amendment to the Fifth Amended and Restated Agreement of Limited Partnership of Crestwood Equity Partners LP entered into and effective as of June 28, 2019 (incorporated by reference to Exhibit 3.1 to Crestwood Equity Partners LP’s Form 8-K filed on June 28, 2019)

67

*10.1	Form of Director and Officer Indemnification Agreement
*31.1	Certification of Chief Executive Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, as amended - Crestwood Equity Partners LP
*31.2	Certification of Chief Financial Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, as amended - Crestwood Equity Partners LP
*31.3	Certification of Chief Executive Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, as amended - Crestwood Midstream Partners LP
*31.4	Certification of Chief Financial Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, as amended - Crestwood Midstream Partners LP
*32.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 - Crestwood Equity Partners LP
*32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 - Crestwood Equity Partners LP
*32.3	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 - Crestwood Midstream Partners LP
*32.4	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 - Crestwood Midstream Partners LP
**101.INS	Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
**101.SCH	Inline XBRL Taxonomy Extension Schema Document
**101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase Document
**101.LAB	Inline XBRL Taxonomy Extension Label Linkbase Document
**101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase Document
**101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase Document
104	Cover Page Interactive Data File (contained in Exhibit 101)

*

Filed herewith

**

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

68

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:	August 6, 2020	By:	/s/ ROBERT T. HALPIN
			Robert T. Halpin
			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:	August 6, 2020	By:	/s/ ROBERT T. HALPIN
			Robert T. Halpin
			Executive Vice President and Chief Financial Officer
			(Duly Authorized Officer and Principal Financial Officer)

69

EX-10.1

Exhibit 10.1

DIRECTOR AND OFFICER INDEMNIFICATION AGREEMENT

         This Director and Officer Indemnification Agreement, dated as of [l], 2020 (this “Agreement”), is made by and between Crestwood Equity GP LLC, a Delaware limited liability company (the “Company”), and [l](“Indemnitee” ).

RECITALS:

WHEREAS, the Company is the general partner of Crestwood Equity Partners LP, a Delaware limited partnership (the “Partnership”), and Indemnitee is a [director/officer] of the Company;

WHEREAS, Section 4.1 of the First Amended and Restated Limited Liability Company Agreement, as amended of the Company (the “LLC Agreement”) provides that the business and affairs of the Company shall be managed by or under the direction of the Board of Directors of the Company.

WHEREAS, significant authority with respect to the management of the Company and, accordingly, the Partnership, has been delegated to the officers of the Company.

WHEREAS, the board of directors of the Company (the “Board”) has determined that enhancing the ability of the Company to retain and attract as directors and officers the most capable persons is in the best interest of the Company and that the Company therefore should seek to assure such person that indemnification and insurance coverage is available;

WHEREAS, both the Company and Indemnitee recognize the increased risk of litigation and other claims being asserted against directors and officers of public companies;

WHEREAS, Indemnitee is a director or officer of the Company and does not regard the protection afforded to him or her by Delaware law and the LLC Agreement as adequate, and his/her willingness to serve in such capacity is predicated, in substantial part, upon (1) the Company’s willingness to provide protection to him/her pursuant to express contract rights providing for the Company to indemnify him/her in accordance with the principles reflected above, to the fullest extent permitted by Delaware law, and (2) the other undertakings set forth in this Agreement; and

WHEREAS, in recognition of the need to provide Indemnitee with substantial protection against personal liability, in order to procure Indemnitee’s continued service as a director or officer of the Company and to enhance Indemnitee’s ability to serve the Company in an effective manner, and in order to provide such protection pursuant to express contract rights (intended to be enforceable irrespective of, among other things, any amendment to the Company’s certificate of formation or the LLC Agreement (collectively, the “Constituent Documents”), any change in the composition of the Board or any change-in-control or business combination transaction relating to the Company), the Company wishes to provide in this Agreement for (1) the indemnification of and the advancement of Expenses (as defined in Section 1(h) below) to Indemnitee as set forth in this Agreement and (2) the continued coverage of Indemnitee under the Company’s directors’ and officers’ liability insurance policies; and

WHEREAS, in light of the considerations referred to in the preceding recitals, it is the Company’s intention and desire that the provisions of this Agreement be construed liberally, subject to their express terms, to maximize the protections to be provided to Indemnitee hereunder.

1

NOW, THEREFORE, in consideration of the foregoing and the Indemnitee’s agreement to continue to provide services to the Company, the parties hereby agree as follows:

AGREEMENT:

1.     Certain Definitions. In addition to terms defined elsewhere herein, the following terms have the following meanings when used in this Agreement with initial capital letters:

(a)    “Affiliate” means, with respect to any Person, any other Person that directly or indirectly through one or more intermediaries controls, is controlled by or is under common control with, the Person in question. As used herein, the term “control” means the possession, direct or indirect, of the power to direct or cause the direction of the management and policies of a Person, whether through ownership of voting securities, by contract or otherwise.

(b)    “Beneficial Owner” has the meaning given to the term “beneficial owner” in Rule 13d-3 under the Exchange Act.

(c)    “Change in Control” means the occurrence after the date of this Agreement of any of the following events:

(i)    The Company ceases to be controlled by Crestwood Holdings or one or more Affiliates of Crestwood Holdings and a majority of the Board of Directors of the Company thereafter ceases to be comprised of Incumbent Directors;

(ii)    The consummation of a reorganization, merger or consolidation of the Partnership or sale or other disposition of all or substantially all of the consolidated assets of the Partnership (a “Partnership Transaction”) immediately after which the voting power of the equity securities of the Partnership outstanding immediately prior to such Partnership Transaction do not continue to represent (either by remaining outstanding or by being converted into equity securities having voting power in the entity surviving, resulting from, or succeeding to all or substantially all of the Partnership’s consolidated assets as a result of such Partnership Transaction or any parent of such entity) at least 50% of the combined voting power of the then outstanding equity securities of (A) the entity surviving, resulting from, or succeeding to all or substantially all of the Partnership’s consolidated assets as a result of such Partnership Transaction or (B) any parent of any such entity (including, without limitation, an entity which as a result of such transaction owns the Partnership or all or substantially all of the Partnership’s assets either directly or through one or more subsidiaries); or

(iii)        The occurrence of any of the following events while the Company is controlled by Crestwood Holdings or one or more Affiliates of Crestwood Holdings:

(A)    Any individual, entity or group (within the meaning of Section 13(d)(3) or 14(d)(2) of the Exchange Act) is or becomes the Beneficial Owner of 50% or more of the combined voting power of the then-outstanding Voting Securities of Crestwood Holdings; provided, however, that the following acquisitions will not constitute a Change in Control: (1) any acquisition of Voting Securities of Crestwood Holdings directly from Crestwood Holdings that is approved by a majority of the Incumbent Crestwood Holdings Directors; (2) any acquisition of the Voting Securities of Crestwood Holdings by Crestwood Holdings or an Affiliate of Crestwood Holdings; or (3) any acquisition of Voting Securities of Crestwood Holdings by the trustee or other fiduciary holding securities under any

2

employee benefit plan (or related trust) sponsored or maintained by Crestwood Holdings or any Affiliate of Crestwood Holdings;

(B)    A majority of the Management Committee of Crestwood Holdings ceases to be comprised of Incumbent Crestwood Holdings Directors;

(C)    The consummation of a reorganization, merger or consolidation of Crestwood Holdings or sale or other disposition of all or substantially all of the consolidated assets of Crestwood Holdings (each, a “Business Combination Transaction”) immediately after which the Voting Securities of Crestwood Holdings outstanding immediately prior to such Business Combination Transaction do not continue to represent (either by remaining outstanding or by being converted into equity securities having voting power in the entity surviving, resulting from, or succeeding to all or substantially all of Crestwood Holdings’ consolidated assets as a result of such Business Combination Transaction or any parent of such entity) at least 50% of the combined voting power of the then outstanding equity securities having voting power in (1) the entity surviving, resulting from, or succeeding to all or substantially all of Crestwood Holdings’ consolidated assets as a result of such Business Combination Transaction or (2) any parent of any such entity (including, without limitation, an entity which as a result of such transaction owns Crestwood Holdings or all or substantially all of Crestwood Holdings’ assets, either directly or through one or more subsidiaries); or

(D)    The Company, or one or more Affiliates of Crestwood Holdings, ceases to be the general partner of the Partnership.

(d)    “Claim” means (i) any threatened, asserted, pending or completed claim, demand, action, suit or proceeding, whether civil, criminal, administrative, arbitrative, investigative or other, and whether made pursuant to federal, state or other law; or (ii) any threatened, pending or completed inquiry, hearing or investigation, whether made, instituted or conducted by the Company or any other person, including any federal, state or other governmental entity, that Indemnitee determines might lead to the institution of any such claim, demand, action, suit, proceeding or alternative dispute resolution mechanism.

(e)    “Controlled Affiliate” means any corporation, limited liability company, partnership, joint venture, trust or other entity or enterprise, whether or not for profit, that is directly or indirectly controlled by the Company. For purposes of this definition, “control” means the possession, directly or indirectly, of the power to direct or cause the direction of the management or policies of an entity or enterprise, whether through the ownership of voting securities, through other voting rights, by contract or otherwise; provided that direct or indirect beneficial ownership of capital stock or other interests in an entity or enterprise entitling the holder to cast 20% or more of the total number of votes generally entitled to be cast in the election of directors (or persons performing comparable functions) of such entity or enterprise shall be deemed to constitute control for purposes of this definition.

(f)    “Disinterested Director” means a director of the Company who is not and was not a party to the Claim in respect of which indemnification is sought by Indemnitee.

(g)    “Exchange Act” means the Securities Exchange Act of 1934, as amended.

(h)    “Expenses” means any and all expenses, including attorneys’ and experts’ fees, court costs, transcript costs, travel expenses, duplicating, printing and binding costs, telephone charges,

3

and all other costs and expenses incurred in connection with investigating, defending, being a witness in or participating in (including on appeal), or preparing to investigate, defend, be a witness in or participate in (including on appeal), any Claim. Expenses also shall include (i) Expenses incurred in connection with any appeal resulting from any Claim, including without limitation the premium, security for, and other costs relating to any cost bond, supersedeas bond, or other appeal bond or its equivalent, and (ii) for purpose of Section 5 only, Expenses incurred by Indemnitee in connection with the interpretation, enforcement or defense of Indemnitee’s rights under this Agreement, by litigation or otherwise. Expenses, however, shall not include amounts paid in settlement by Indemnitee or the amount of judgments or fines against Indemnitee unless otherwise provided for herein. The parties agree that for the purposes of any advancement of Expenses for which Indemnitee has made written demand to the Company in accordance with this Agreement, all Expenses included in such demand that are certified by affidavit of Indemnitee’s counsel as being reasonable shall be presumed conclusively to be reasonable.

(i)    “Incumbent Crestwood Holdings Directors” means the individuals who, as of the date hereof, are members of the Management Committee of Crestwood Holdings Partners, LLC (“Crestwood Holdings”), and any individual becoming a member of the Management Committee of Crestwood Holdings subsequent to such date whose election or appointment, was approved by a vote of a majority of the then Incumbent Crestwood Holdings Directors (either by a specific vote or by approval of the proxy statement of Crestwood Holdings in which such person is named as a nominee for director, without objection to such nomination).

(j)    “Incumbent Directors” means the individuals who, as of the date hereof, are directors of the Company, and any individual becoming a director of the Company subsequent to such date whose election, nomination for election by the Company’s members, or appointment, was approved by a vote of a majority of the then Incumbent Directors (either by a specific vote or by approval of the proxy statement of the Company in which such person is named as a nominee for director, without objection to such nomination).

(k)    “Indemnifiable Claim” means any Claim based upon, arising out of or resulting from (i) any actual, alleged or suspected act or failure to act by Indemnitee in his or her capacity as a director, officer, employee or agent of the Company or Crestwood Holdings or as a director, officer, employee, member, manager, trustee or agent of any other corporation, limited liability company, partnership, joint venture, trust or other entity or enterprise, whether or not for profit, as to which Indemnitee is or was serving at the request of the Company or Crestwood Holdings as a director, officer, employee, member, manager, trustee or agent, (ii) any actual, alleged or suspected act or failure to act by Indemnitee in respect of any business, transaction, communication, filing, disclosure or other activity of the Company or any other entity or enterprise referred to in clause (i) of this sentence, or (iii) Indemnitee’s status as a current or former director, officer, employee or agent of the Company or as a current or former director, officer, employee, member, manager, trustee or agent of the Company or any other entity or enterprise referred to in clause (i) of this sentence or any actual, alleged or suspected act or failure to act by Indemnitee in connection with any obligation or restriction imposed upon Indemnitee by reason of such status. In addition to any service at the actual request of the Company, for purposes of this Agreement, Indemnitee shall be deemed to be serving or to have served at the request of the Company as a director, officer, employee, member, manager, trustee or agent of another entity or enterprise if Indemnitee is or was serving as a director, officer, employee, member, manager, trustee or agent of such entity or enterprise and (i) such entity or enterprise is or at the time of such service was a Controlled Affiliate, (ii) such

4

entity or enterprise is or at the time of such service was an employee benefit plan (or related trust) sponsored or maintained by the Company or a Controlled Affiliate, or (iii) the Company or a Controlled Affiliate directly or indirectly caused or authorized Indemnitee to be nominated, elected, appointed, designated, employed, engaged or selected to serve in such capacity.

(l)    “Indemnifiable Losses” means any and all Losses relating to, arising out of or resulting from any Indemnifiable Claim.

(m)    “Independent Counsel” means a law firm, or a member of a law firm, that is experienced in matters of corporation, limited liability company, and/or partnership law and neither presently is, nor in the past five years has been, retained to represent: (i) the Company (or any Subsidiary of the Company) or Indemnitee in any matter material to either such party (other than with respect to matters concerning Indemnitee under this Agreement, or of other indemnitees under similar indemnification agreements), or (ii) any other named (or, as to a threatened matter, reasonably likely to be named) party to the Indemnifiable Claim giving rise to a claim for indemnification hereunder. Notwithstanding the foregoing, the term “Independent Counsel” shall not include any person who, under the applicable standards of professional conduct then prevailing, would have a conflict of interest in representing either the Company or Indemnitee in an action to determine Indemnitee’s rights under this Agreement.

(n)    “Losses” means any and all Expenses, damages, losses, liabilities, judgments, fines, penalties (whether civil, criminal or other), ERISA excise taxes, amounts paid or payable in settlement, including all interest, assessments, any federal, state, local or foreign taxes imposed as a result of the actual or deemed receipt of any payments under this Agreement and all other charges paid or payable in connection with investigating, defending, being a witness in or participating in (including on appeal), or preparing to defend, be a witness or participate in, any Claim.

(o)    “Person” means an individual, corporation, firm, limited liability company, partnership, joint venture, estate, trust, unincorporated organization, association, government agency or political subdivision thereof or other entity and includes the meaning set forth in Sections 13(d) and 14(d) of the Exchange Act.

(p)    “Subsidiary” of a Person means a corporation, partnership, limited liability company or other entity in which such Person owns directly or indirectly more than 50% of the outstanding shares of voting stock or other voting interest.

(q)    “Voting Securities” means the securities entitled to vote generally in the election of directors or persons who serve similar functions.

2.    Service to the Company. Indemnitee agrees to [serve/continue to serve] as a director or officer of the Company for so long as Indemnitee is duly elected or appointed or until Indemnitee tenders [his/her] resignation or is no longer serving in such capacity. This Agreement shall not be deemed an employment agreement between the Company (or any of its Subsidiaries or Controlled Affiliates) and Indemnitee. Indemnitee specifically acknowledges that [his/her] [employment with/service to] the Company or any of its Subsidiaries or Controlled Affiliates is at will and the Indemnitee may be discharged at any time for any reason, with or without cause, except as may be otherwise provided in any written agreement between Indemnitee and the Company (or any of its Subsidiaries or Controlled Affiliates), or other applicable formal severance policies duly adopted by the Board or, with respect to service as a director or officer of the Company, by the Company’s Constituent Documents or Delaware law. This Agreement shall continue in force after Indemnitee

5

has ceased to serve as a director or officer of the Company or, at the request of the Company, or any of its Subsidiaries or Controlled Affiliates, as provided in Section 12hereof.

3.    Indemnification Obligation. Subject to Section 7 and Section 8 of this Agreement, the Company shall indemnify, defend and hold harmless Indemnitee, to the fullest extent permitted by the laws of the State of Delaware in effect on the date hereof or as such laws may from time to time hereafter be amended to increase the scope of such permitted indemnification, against any and all Indemnifiable Claims and Indemnifiable Losses.

4.    Advancement of Expenses. Indemnitee shall have the right to advancement by the Company, prior to the final disposition of any Indemnifiable Claim to which there are no further rights of appeal, of any and all Expenses relating to, arising out of or resulting from any Indemnifiable Claim actually and reasonably paid or incurred by Indemnitee or which Indemnitee determines are reasonably likely to be paid or incurred by Indemnitee.‎ Indemnitee’s right to such advancement is not subject to the satisfaction of any standard of conduct. Without limiting the generality or effect of the foregoing, within five business days after any request by Indemnitee, the Company shall, in accordance with such request (but without duplication), (a) pay such Expenses on behalf of Indemnitee, (b) advance to Indemnitee funds in an amount sufficient to pay such Expenses, or (c) reimburse Indemnitee for such Expenses. In connection with any request for Expense Advances, Indemnitee shall not be required to provide any documentation or information to the extent that the provision thereof would undermine or otherwise jeopardize attorney-client privilege. In connection with any request for Expense Advances, Indemnitee shall execute and deliver to the Company an undertaking (which shall be accepted without reference to Indemnitee’s ability to repay the Expense Advances), in the form attached hereto as Exhibit A, to repay any amounts paid, advanced, or reimbursed by the Company for such Expenses to the extent that it is ultimately determined, following the final disposition of such Claim, that Indemnitee is not entitled to indemnification hereunder. Indemnitee’s obligation to reimburse the Company for Expense Advances shall be unsecured and no interest shall be charged thereon.

5.    Indemnification for Expenses in Enforcing Rights. Without limiting the generality or effect of the foregoing and to the fullest extent allowable under applicable law, the Company shall also indemnify against and, if requested by Indemnitee, shall advance to Indemnitee subject to and in accordance with Section 3, any and all Expenses actually and reasonably paid or incurred by Indemnitee or which Indemnitee determines are reasonably likely to be paid or incurred by Indemnitee in connection with any Claim made, instituted or conducted by Indemnitee for (a) indemnification or reimbursement or advance payment of Expenses by the Company under any provision of this Agreement, or under any other agreement or provision of the Constituent Documents now or hereafter in effect relating to Indemnifiable Claims, and/or (b) recovery under any directors’ and officers’ liability insurance policies maintained by the Company, regardless in each case of whether Indemnitee ultimately is determined to be entitled to such indemnification, reimbursement, advance or insurance recovery, as the case may be; provided, however, that Indemnitee shall return, without interest, any such advance of Expenses (or portion thereof) which remains unspent at the final disposition of the Claim to which the advance related. Notwithstanding anything to the contrary herein, Indemnitee shall be required to reimburse the Company in the event that a final judicial determination is made that such action brought by Indemnitee was frivolous or not made in good faith.

6

6.    Partial Indemnity. If Indemnitee is entitled under any provision of this Agreement to indemnification by the Company for some or a portion of any Indemnifiable Loss, but not for all of the total amount thereof, the Company shall nevertheless indemnify Indemnitee for the portion thereof to which Indemnitee is entitled.

7.    Notification and Defense of Claims.

(a)    Notification of Claims. Indemnitee shall notify the Company in writing as soon as practicable of any Indemnifiable Claim or Indemnifiable Loss for which Indemnitee could seek Expense Advances, including a brief description (based upon information then available to Indemnitee) of the nature of, and the facts underlying, such Indemnifiable Claim or Indemnifiable Loss. If, at the time of the receipt of such notice, the Company has directors’ and officers’ liability insurance in effect under which coverage for such Indemnifiable Claim or Indemnifiable Loss is potentially available, the Company shall give prompt written notice of such Indemnifiable Claim or Indemnifiable Loss to the applicable insurers in accordance with the procedures set forth in the applicable policies. The Company shall provide to Indemnitee a copy of such notice delivered to the applicable insurers, and copies of all subsequent correspondence between the Company and such insurers regarding the Indemnifiable Claim or Indemnifiable Loss, in each case substantially concurrently with the delivery or receipt thereof by the Company. The failure by Indemnitee to timely notify the Company of any Indemnifiable Claim or Indemnifiable Loss shall not relieve the Company from any liability hereunder unless, and only to the extent that, the Company did not otherwise learn of such Indemnifiable Claim or Indemnifiable Loss and such failure results in forfeiture by the Company of substantial defenses, rights or insurance coverage.

(b)    Defense of Claims. The Company shall be entitled to participate in the defense of any Indemnifiable Claim at its own expense and, except as otherwise provided below, to the extent the Company so wishes, it may assume the defense thereof with counsel reasonably satisfactory to Indemnitee. After notice from the Company to Indemnitee of its election to assume the defense of any Indemnifiable Claim, the Company shall not be liable to Indemnitee under this Agreement or otherwise for any Expenses subsequently directly incurred by Indemnitee in connection with Indemnitee’s defense of such Indemnifiable Claim other than reasonable costs of investigation or as otherwise provided below. Indemnitee shall have the right to employ [his/her] own legal counsel in such Indemnifiable Claim, but all Expenses related to such counsel incurred after notice from the Company of is assumption of the defense shall be at Indemnitee’s own expenses; provided, however, that if (i) Indemnitee’s employment of its own legal counsel has been authorized by the Company, (ii) Indemnitee has reasonably determined that there may be a conflict of interest between Indemnitee and the Company in the defense of such Indemnifiable Claim, (iii) after a Change in Control, Indemnitee’s employment of its counsel has been approved by the Independent counsel, (iv) the use of counsel chosen by the Company to represent Indemnitee would present such counsel with an actual or potential conflict, (v) the named parties in any such Indemnifiable Claim (including any impleaded parties) include both the Company and Indemnitee and Indemnitee shall conclude that there may be one or more legal defenses available to him or her that are different from or in addition to those available to the Company, (vi) any such representation by counsel chosen by the Company would be precluded under the applicable standards of professional conduct then prevailing or (vii) the Company shall not in fact have employed counsel to assume the defense of such Indemnifiable Claim, then Indemnitee shall be entitled to retain separate counsel (but not more than one law firm plus, if applicable, local counsel in respect of any particular Indemnifiable Claim) and all Expenses related to such separate counsel shall be borne by the Company.

7

8.    Procedure upon Application for Indemnification. In order to obtain indemnification pursuant to this Agreement, Indemnitee shall submit to the Company a written request therefor, including in such request such documentation and information as is reasonably available to Indemnitee and is reasonably necessary to determine whether and to what extent Indemnitee is entitled to indemnification following the final disposition of the Indemnifiable Claim, provided that documentation and information need not be so provided to the extent that the provision thereof would undermine or otherwise jeopardize attorney-client privilege. Indemnification shall be made insofar as the Company determines Indemnitee is entitled to indemnification in accordance with Section 9 below.

9.    Determination of Right to Indemnification.

(a)    Mandatory Indemnification; Indemnification as a Witness.

(i)    To the extent that Indemnitee shall have been successful on the merits or otherwise in defense of any Indemnifiable Claim or any portion thereof or in defense of any issue or matter therein, including dismissal without prejudice, Indemnitee shall be indemnified against all Indemnifiable Losses relating to, arising out of or resulting from such Indemnifiable Claim in accordance with Section 3 to the fullest extent allowable by law, and no Standard of Conduct Determination (as defined in Section 9(b)) shall be required.

(ii)    To the extent that Indemnitee’s involvement in an Indemnifiable Claim is to prepare to serve and serve as a witness, and not as a party, the Indemnitee shall be indemnified against all Indemnifiable Losses incurred in connection therewith to the fullest extent allowable by law, and no Standard of Conduct Determination (as defined in Section 9(b)) shall be required.

(b)    Standard of Conduct. To the extent that the provisions of Section 9(a) are inapplicable to an Indemnifiable Claim that shall have been finally disposed of, any determination of whether Indemnitee has satisfied any applicable standard of conduct under Delaware law that is a legally required condition precedent to indemnification of Indemnitee hereunder against Indemnifiable Losses relating to, arising out of or resulting from such Indemnifiable Claim and any determination that Expense Advances must be repaid to the Company (a“Standard of Conduct Determination”) shall be made as follows:

(i)    if a Change in Control shall not have occurred, or if a Change in Control shall have occurred but Indemnitee shall have requested that the Standard of Conduct Determination be made pursuant to this clause (i), (A) by a majority vote of the Disinterested Directors, even if less than a quorum of the Board, (B) if such Disinterested Directors so direct, by a majority vote of a committee of Disinterested Directors designated by a majority vote of all Disinterested Directors, or (C) if there are no such Disinterested Directors, by Independent Counsel in a written opinion addressed to the Board, a copy of which shall be delivered to Indemnitee; and

(ii)    if a Change in Control shall have occurred and Indemnitee shall not have requested that the Standard of Conduct Determination be made pursuant to clause (i), by Independent Counsel in a written opinion addressed to the Board, a copy of which shall be delivered to Indemnitee.

Indemnitee will cooperate with the person or persons making such Standard of Conduct Determination, including providing to such person or persons, upon reasonable advance request, any documentation or information which is not privileged or otherwise protected from disclosure and which is reasonably available to Indemnitee and reasonably necessary to such determination.

8

The Company shall indemnify and hold harmless Indemnitee against and, if requested by Indemnitee, shall reimburse Indemnitee for, or advance to Indemnitee, within five business days of such request, any and Expenses incurred by Indemnitee in so cooperating with the person or persons making such Standard of Conduct Determination.

(c)    Making the Standard of Conduct Determination. The Company shall use its reasonable best efforts to cause any Standard of Conduct Determination required under Section 9(b) to be made as promptly as practicable. If (i) the person or persons empowered or selected under Section 9(b) to make the Standard of Conduct Determination shall not have made a determination within 30 days after the later of (A) receipt by the Company of written notice from Indemnitee for indemnification pursuant to Section 8 (the date of such receipt being the“Notification Date”) and (B) the selection of an Independent Counsel, if such determination is to be made by Independent Counsel, that is permitted under the provisions of Section 9(e) to make such determination and (ii) Indemnitee shall have fulfilled his/her obligations set forth in the first sentence of the last paragraph of Section 9(b), then Indemnitee shall be deemed to have satisfied the applicable standard of conduct; provided that such 30-day period may be extended for a reasonable time, not to exceed an additional 30 days, if the person or persons making such determination in good faith requires such additional time for the obtaining or evaluation or documentation and/or information relating thereto. Notwithstanding anything in this Agreement to the contrary, no determination as to entitlement of Indemnitee to indemnification under this Agreement shall be required to be made prior to the final disposition of any Indemnifiable Claim.

(d)    Payment of Indemnification. If (i) Indemnitee shall be entitled to indemnification hereunder against any Indemnifiable Losses pursuant to Section 9(a), (ii) no Standard of Conduct Determination is legally required as a condition to indemnification of Indemnitee hereunder against any Indemnifiable Losses, or (iii) Indemnitee has been determined or deemed pursuant to Section 9(b) or 9(c) to have satisfied any applicable Standard of Conduct Determination, then the Company shall pay to Indemnitee, within five business days after the later of (A) the Notification Date in respect of the Indemnifiable Claim or portion thereof to which such Indemnifiable Losses are related, out of which such Indemnifiable Losses arose or from which such Indemnifiable Losses resulted and (B) the earliest date on which the applicable criterion specified in clause (i), (ii) or (iii) above shall have been satisfied, an amount equal to the amount of such Indemnifiable Losses.

(e)    Selection of Independent Counsel for Standard of Conduct Determination. If a Standard of Conduct Determination is to be made by Independent Counsel pursuant to Section 9(b)(i), the Independent Counsel shall be selected by the Board of Directors, and the Company shall give written notice to Indemnitee advising [him/her] of the identity of the Independent Counsel so selected. If a Standard of Conduct Determination is to be made by Independent Counsel pursuant to Section 9(b)(ii), the Independent Counsel shall be selected by Indemnitee, and Indemnitee shall give written notice to the Company advising it of the identity of the Independent Counsel so selected. In either case, Indemnitee or the Company, as applicable, may, within five business days after receiving written notice of selection from the other, deliver to the other a written objection to such selection; provided, however, that such objection may be asserted only on the ground that the Independent Counsel so selected does not satisfy the criteria set forth in the definition of “Independent Counsel” in Section 1(m), and the objection shall set forth with particularity the factual basis of such assertion. Absent a proper and timely objection, the person or firm so selected shall act as Independent Counsel. If such written objection is properly and timely made and substantiated, (i) the Independent Counsel so selected may not serve as Independent Counsel unless and until such

9

objection is withdrawn or a court has determined that such objection is without merit and (ii) the non-objecting party may, at its option, select an alternative Independent Counsel and give written notice to the other party advising such other party of the identity of the alternative Independent Counsel so selected, in which case the provisions of the two immediately preceding sentences and clause (i) of this sentence shall apply to such subsequent selection and notice. If applicable, the provisions of clause (ii) of the immediately preceding sentence shall apply to successive alternative selections. If no Independent Counsel that is permitted under the foregoing provisions of this Section 9(e) to make the Standard of Conduct Determination shall have been selected within 30 days after the Company gives its initial notice pursuant to the first sentence of this Section 9(e) or Indemnitee gives its initial notice pursuant to the second sentence of this Section 9(e), as the case may be, either the Company or Indemnitee may petition the Court of Chancery of the State of Delaware (“Delaware Court”) to resolve any objection which shall have been made by the Company or Indemnitee to the other’s selection of Independent Counsel and/or for the appointment as Independent Counsel of a person or firm selected by the Court or by such other person as the Delaware Court shall designate, and the person or firm with respect to whom all objections are so resolved or the person or firm so appointed will act as Independent Counsel. In all events, the Company shall pay all of the reasonable fees and expenses of the Independent Counsel incurred in connection with the Independent Counsel’s determination pursuant to Section 9(b).

(f)    Presumption and Defenses.

(i)    Indemnitee’s Entitlement to Indemnification. In making any Standard of Conduct Determination, the person or persons making such determination shall presume that Indemnitee has satisfied the applicable standard of conduct and is entitled to indemnification, and the Company may overcome such presumption only by its adducing clear and convincing evidence to the contrary. Any Standard of Conduct Determination that is adverse to Indemnitee may be challenged by Indemnitee in the Delaware Court. No determination by the Company (including by its directors or any Independent Counsel) that Indemnitee has not satisfied any applicable standard of conduct shall be a defense to any legal proceedings brought by Indemnitee to secure indemnification or reimbursement or advance payment of Expenses by the Company hereunder or create a presumption that Indemnitee has not met any applicable standard of conduct.

(ii)    Reliance as a Safe Harbor. For purposes of this Agreement, and without creating any presumption as to a lack of good faith if the following circumstances do not exist, Indemnitee shall be deemed to have acted in good faith and in a manner [he/she] reasonably believed to be in or not opposed to the best interest of the Company if Indemnitee’s actions or omissions to act are taken in good faith reliance upon the records of the Company, including its financial statements, or upon information, opinions, reports or statements furnished to Indemnitee by the officers or employees of the Company or any of its subsidiaries in the course of their duties, or by committees of the Board or by any other Person (including legal counsel, accountants and financial advisors) as to matters Indemnitee reasonably believes are within such other Person’s professional or expert competence and who has been selected with reasonable care by or on behalf of the Company. In addition, the knowledge and/or actions, or failures to act, of any director, officer, agent or employee of the Company shall not be imputed to Indemnitee for purposes of determining the right to indemnity hereunder..

(iii)    No Other Presumptions. For purposes of this Agreement, the termination of any Claim by judgment, order, settlement (whether with or without court approval) or conviction, or upon a

10

plea of nolo contendere or its equivalent, will not create a presumption that Indemnitee did not meet any applicable standard of conduct or have any particular belief, or that indemnification hereunder is otherwise not permitted.

(iv)    Defense to Indemnification and Burden of Proof. It shall be a defense to any action brought by Indemnitee against the Company to enforce this Agreement (other than an action brought to enforce a claim for Indemnifiable Losses incurred in defending against an Indemnifiable Claim in advance of its final disposition) that it is not permissible under applicable law for the Company to indemnify Indemnitee for the amount claimed. In connection with any such action or any related Standard of Conduct Determination, the burden of proving such a defense or that the Indemnitee did not satisfy the applicable standard of conduct shall be on the Company.

(v)    Resolution of Claims. The Company acknowledges that a settlement or other disposition short of final judgment may be successful on the merits or otherwise for purposes of Section 9.1(a)(i) if it permits a party to avoid expense, delay, distraction, disruption and uncertainty. In the event that any Indemnifiable Claim to which Indemnitee is a party is resolved in any manner other than by adverse judgment against Indemnitee (including, without limitation, settlement or such action, claim or proceeding with or without payment of money or other consideration) it shall be presumed that Indemnitee has been successful on the merits or otherwise for purposes of Section 9.1(a)(i). The Company shall have the burden of proof to overcome this presumption.

10.    Exclusions from Indemnification. Notwithstanding anything in this Agreement to the contrary, the Company shall not be obligated to:

(a)    indemnify or advance funds to Indemnitee for Expenses or Losses with respect to proceedings initiated by Indemnitee, including any proceedings against the Company or its directors, officers, employees or other indemnitees and not by way of defense, except:

(i)    proceedings referenced in Section 5 above (unless a court of competent jurisdiction determines that each of the material assertions made by Indemnitee in such proceeding was not made in good faith or was frivolous); or

(ii)    where the Company has joined in or the Board has consented to the initiation of such proceedings.

(b)    indemnify Indemnitee if a final decision by a court of competent jurisdiction determines that such indemnification is prohibited by applicable law.

(c)    indemnify Indemnitee for the disgorgement of profits arising from the purchase or sale by Indemnitee of securities of the Company in violation of Section 16(b) of the Exchange Act, or any similar successor statute.

(d)    indemnify or advance funds to Indemnitee for Indemnitee’s reimbursement to the Company or any bonus or other incentive-based or equity-based compensation previously received by Indemnitee from the sale of securities of the Company, as required in each case under the Exchange Act (including any such reimbursements under Section 304 of the Sarbanes-Oxley Act of 2002 in connection with an accounting restatement of the Company or the payment to the Company of profits arising from the purchase or sale by Indemnitee of securities in violation of Section 306 of the Sarbanes-Oxley Act).

11

11.    Settlement of Claims. The Company shall not be liable to Indemnitee under this Agreement for any amounts paid in settlement of any threatened or pending Indemnifiable Claim effected without the Company’s prior written consent; provided, however, that if a Change in Control has occurred, the Company shall be liable for indemnification of the Indemnitee for amounts paid in settlement if an Independent Counsel has approved the settlement. The Company shall not be liable to Indemnitee under this Agreement for any amounts paid in settlement of any threatened or pending Indemnifiable Claim effected without the Company’s prior written consent. The Company shall not, without the prior written consent of Indemnitee, effect any settlement of any threatened or pending Indemnifiable Claim in any manner that would impose any Losses on Indemnitee or to which Indemnitee is, or could have been, a party unless such settlement solely involves the payment of money and includes a complete and unconditional release of Indemnitee from all liability on any claims that are the subject matter of such Indemnifiable Claim. Neither the Company nor Indemnitee shall unreasonably withhold its consent to any proposed settlement; provided that Indemnitee may withhold consent to any settlement that does not provide a complete and unconditional release of Indemnitee.

12.    Duration. All agreements and obligations of the Company contained herein shall continue during the period that Indemnitee is a director or officer of the Company (or is serving at the request of the Company as a director, officer, employee, member, trustee or agent of a Controlled Affiliate) and shall continue thereafter (i) so long as Indemnitee may be subject to any possible Indemnifiable Claim (including any rights of appeal thereto) and (ii) throughout the pendency of any proceeding (including any rights of appeal thereto) commenced by Indemnitee to enforce or interpret [his/her] rights under this Agreement, even if, in either case, [he/she] may have ceased to serve in such capacity at the time of any such Indemnifiable Claim or proceeding.

13.    Non-Exclusivity. The rights of Indemnitee hereunder will be in addition to any other rights Indemnitee may have under the Constituent Documents, or the substantive laws of the Company’s jurisdiction of formation, any other contract or otherwise (collectively,“Other Indemnity Provisions” ); provided, however, that (a) to the extent that Indemnitee otherwise would have any greater right to indemnification under any Other Indemnity Provision, Indemnitee will be deemed to have such greater right hereunder and (b) to the extent that any change is made to any Other Indemnity Provision which permits any greater right to indemnification than that provided under this Agreement as of the date hereof, Indemnitee will be deemed to have such greater right hereunder. Except as set forth in the proviso to the immediately preceding sentence, the Other Indemnity Provisions shall not be taken into account in construing or applying the provisions of this Agreement, which are intended to operate independently of the Other Indemnity Provisions. The Company will not adopt any amendment to any of the Constituent Documents the effect of which would be to deny, diminish or encumber Indemnitee’s right to indemnification under this Agreement or any Other Indemnity Provision.

14.    Liability Insurance and Funding. For the duration of Indemnitee’s service as a [director/officer] of the Company, and thereafter for so long as Indemnitee shall be subject to any pending or possible Indemnifiable Claim, the Company shall use commercially reasonable efforts (taking into account the scope and amount of coverage available relative to the cost thereof) to cause to be maintained in effect policies of directors’ and officers’ liability insurance providing coverage for directors and/or officers of the Company that is at least substantially comparable in scope and amount to that provided by the Company’s current policies of directors’ and officers’ liability insurance. Upon request, the Company shall provide Indemnitee with a copy of all directors’ and

12

officers’ liability insurance applications, binders, policies, declarations, endorsements and other related materials, and shall provide Indemnitee with a reasonable opportunity to review and comment on the same. Without limiting the generality or effect of the two immediately preceding sentences, the Company shall not discontinue or significantly reduce the scope or amount of coverage from one policy period to the next (i) without the prior approval thereof by a majority vote of the Incumbent Directors, even if less than a quorum, or (ii) if at the time that any such discontinuation or significant reduction in the scope or amount of coverage is proposed there are no Incumbent Directors, without the prior written consent of Indemnitee (which consent shall not be unreasonably withheld or delayed). In all policies of directors’ and officers’ liability insurance maintained by the Company, Indemnitee shall be named as an insured in such a manner as to provide Indemnitee the same rights and benefits, subject to the same limitations, as are provided to the most favorably insured of the Company’s directors, if Indemnitee is a director, or of the Company’s officers, if Indemnitee is an officer (and not an a director) by such policy. The Company may, but shall not be required to, create a trust fund, grant a security interest or use other means, including a letter of credit, to ensure the payment of such amounts as may be necessary to satisfy its obligations to indemnify and advance expenses pursuant to this Agreement.

15.    Subrogation. In the event of payment under this Agreement, the Company shall be subrogated to the extent of such payment to all of the rights of recovery of Indemnitee against other Persons (other than Indemnitee’s successors), including any entity or enterprise referred to in clause (i) of the definition of “Indemnifiable Claim” in Section 1(k). Indemnitee shall execute all papers reasonably required and shall do everything that may be necessary to secure such rights, including the execution of such documents necessary to enable the Company effectively to bring suit to enforce such rights.

16.    No Duplication of Payments. The Company shall not be liable under this Agreement to make any payment to Indemnitee in respect of any Indemnifiable Losses to the extent Indemnitee has otherwise actually received payment (net of Expenses incurred in connection therewith) under any insurance policy, the Constituent Documents, Other Indemnity Provisions or otherwise (including from any entity or enterprise referred to in clause (i) of the definition of “Indemnifiable Claim” in Section 1(k)) in respect of such Indemnifiable Losses otherwise indemnifiable by the Company hereunder.

17.    Binding Agreement; Successors and Assignment.

(a)    Binding Agreement. This Agreement shall be binding upon and inure to the benefit of and be enforceable by the parties hereto and their respective successors (including any direct or indirect successor by purchase, merger, consolidation, reorganization or otherwise to all or substantially all of the business and/or assets of the Company (and such successor will thereafter be deemed the “Company” for purposes of this Agreement), assigns, spouses, heirs and personal and legal representative. The Company shall require and cause any successor (whether direct or indirect, by purchase, merger, consolidation, reorganization or otherwise) to all, substantially all or a substantial part of the business and/or assets of the Company, by written agreement in form and substance satisfactory to Indemnitee and [his/her] counsel, expressly to assume and agree to perform this Agreement in the same manner and to the same extent the Company would be required to perform if no such succession had taken place.

(b)    Assignment. This Agreement is personal in nature and neither of the parties hereto shall, without the consent of the other, assign or delegate this Agreement or any rights or obligations

13

hereunder except as expressly provided in Section 17(a). Without limiting the generality or effect of the foregoing, Indemnitee’s right to receive payments hereunder shall not be assignable, whether by pledge, creation of a security interest or otherwise, other than by a transfer by Indemnitee’s will or by the laws of descent and distribution, and, in the event of any attempted assignment or transfer contrary to this Section 17(b), the Company shall have no liability to pay any amount so attempted to be assigned or transferred.

18.    Notices. For all purposes of this Agreement, all communications, including notices, consents, requests or approvals, required or permitted to be given hereunder shall be in writing and shall be deemed to have been duly given when hand delivered or dispatched by electronic facsimile transmission (with receipt thereof orally confirmed), or five business days after having been mailed by United States registered or certified mail, return receipt requested, postage prepaid or one business day after having been sent for next-day delivery by a nationally recognized overnight courier service, addressed to the Company (to the attention of the Secretary of the Company) and to Indemnitee at the applicable address shown on the signature page hereto, or to such other address as any party may have furnished to the other in writing and in accordance herewith, except that notices of changes of address will be effective only upon receipt.

19.    Governing Law and Forum. The validity, interpretation, construction and performance of this Agreement shall be governed by and construed in accordance with the substantive laws of the State of Delaware applicable to contracts made and to be performed in such state without giving effect to the principles of conflict of laws of such State. The Company and Indemnitee each hereby irrevocably and unconditionally (a) agree that any action or proceeding arising out of or in connection with this Agreement shall be brought only in the Delaware Court and not in any other state or federal court in the United States, (b) consent to submit to the exclusive jurisdiction of the Delaware Court for purposes of any action or proceeding arising out of or in connection with this Agreement, and (d) waive, and agree not to plead or make, any claim that the Delaware Court lacks venue or that any such action or proceeding brought in the Delaware Court has been brought in an improper or inconvenient forum.

20.    Validity. If any provision of this Agreement or the application of any provision hereof to any Person or circumstance is held by a court of competent jurisdiction to be invalid, unenforceable or otherwise illegal, the remainder of this Agreement and the application of such provision to any other Person or circumstance shall not be affected, and the provision so held to be invalid, unenforceable or otherwise illegal shall be reformed to the extent, and only to the extent, necessary to make it enforceable, valid or legal. In the event that any court of competent jurisdiction or other adjudicative body shall decline to reform any provision of this Agreement held to be invalid, unenforceable or otherwise illegal as contemplated by the immediately preceding sentence, the parties hereto shall take all such action as may be necessary or appropriate to replace the provision so held to be invalid, unenforceable or otherwise illegal with one or more alternative provisions that effectuate the purpose and intent of the original provisions of this Agreement as fully as possible without being invalid, unenforceable or otherwise illegal.

21.    Amendments and Waivers. No supplement, modification or amendment of this Agreement shall be binding unless executed in writing by both parties hereto. No wavier of any of the provisions of this Agreement shall be binding unless in the form of a writing signed by the party against whom enforcement of the waiver is sought, and no such waiver shall operate as a waiver of any other provisions hereof (whether or not similar), nor shall such waiver constitute a continuing

14

waiver. Except as specifically provided herein, no failure to exercise or delay in exercising any right or remedy hereunder shall constitute a waiver thereof. No agreements or representations, oral or otherwise, expressed or implied with respect to the subject matter hereof have been made by either party that are not set forth expressly in this Agreement.

22.    Legal Fees and Expenses. It is the intent of the Company that Indemnitee not be required to incur legal fees and or other Expenses associated with the interpretation, enforcement or defense of Indemnitee’s rights under this Agreement by litigation or otherwise because the cost and expense thereof would substantially detract from the benefits intended to be extended to Indemnitee hereunder. Accordingly, without limiting the generality or effect of any other provision hereof, if it should appear to Indemnitee that the Company has failed to comply with any of its obligations under this Agreement or in the event that the Company or any other Person takes or threatens to take any action to declare this Agreement void or unenforceable, or institutes any litigation or other action or proceeding designed to deny, or to recover from, Indemnitee the benefits provided or intended to be provided to Indemnitee hereunder, the Company irrevocably authorizes Indemnitee from time to time to retain counsel of Indemnitee’s choice, at the expense of the Company as hereafter provided, to advise and represent Indemnitee in connection with any such interpretation, enforcement or defense, including the initiation or defense of any litigation or other legal action, whether by or against the Company or any director, officer, member or other person affiliated with the Company, in any jurisdiction. Notwithstanding any existing or prior attorney-client relationship between the Company and such counsel, the Company irrevocably consents to Indemnitee’s entering into an attorney-client relationship with such counsel, and in that connection the Company and Indemnitee agree that a confidential relationship shall exist between Indemnitee and such counsel. Without respect to whether Indemnitee prevails, in whole or in part, in connection with any of the foregoing, the Company will pay and be solely financially responsible for any and all attorneys’ and related fees and expenses incurred by Indemnitee in connection with any of the foregoing.

23.    Certain Interpretive Matters. Unless the context of this Agreement otherwise requires, (a) “it” or “its” or words of any gender include each other gender, (b) words using the singular or plural number also include the plural or singular number, respectively, (c) the terms “hereof,” “herein,” “hereby” and derivative or similar words refer to this entire Agreement, (d) the terms “Article,” “Section,” “Annex” or “Exhibit” refer to the specified Article, Section, Annex or Exhibit of or to this Agreement, (e) the terms “include,” “includes” and “including” will be deemed to be followed by the words “without limitation” (whether or not so expressed), and (f) the word “or” is disjunctive but not exclusive. Whenever this Agreement refers to a number of days, such number will refer to calendar days unless business days are specified and whenever action must be taken (including the giving of notice or the delivery of documents) under this Agreement during a certain period of time or by a particular date that ends or occurs on a non-business day, then such period or date will be extended until the immediately following business day. As used herein, “business day” means any day other than Saturday, Sunday or a United States federal holiday. The Section headings contained in this Agreement are inserted for convenience only and do not constitute a part of this Agreement.

24.    Counterparts. This Agreement may be executed in one or more counterparts, each of which will be deemed to be an original but all of which together shall constitute one and the same agreement.

[Signatures Appear On Following Page]

15

IN WITNESS WHEREOF, Indemnitee has executed and the Company has caused its duly authorized representative to execute this Agreement as of the date first above written.

CRESTWOOD EQUITY GP LLC 811 Main Street, Suite 3400  Houston, Texas 77002
By:
	Name
	Title:
[DIRECTOR/OFFICER] [ADDRESS] [ADDRESS] [ADDRESS] [CITY, STATE, ZIP CODE]
[NAME]

16

EXHIBIT A

FORM OF UNDERTAKING TO REPAY ADVANCEMENT OF EXPENSES

[DATE]

[OFFICER(S) TO WHOM NOTICE IS DELIVERED]

Crestwood Equity GP LLC

811 Main Street, Suite 3400

Houston, Texas 77002

Re: Undertaking to Repay Advancement of Expenses.

Dear [ADDRESSEE]]:

This undertaking is being provided pursuant to that certain Indemnification Agreement, dated [DATE], by and between Crestwood Equity GP LLC, a Delaware limited liability company (the “Company”), and the undersigned as Indemnitee (the “Indemnification Agreement”). Terms used herein and not otherwise defined shall have the meanings ascribed to them in the Indemnification Agreement. Pursuant to the Indemnification Agreement, among other things, I am entitled to the advancement of Expenses paid or incurred in connection with Indemnifiable Claims.

I have become subject to [DESCRIPTION OF PROCEEDING] (the “Proceeding”) based on [my status as [an officer/[TITLE OF OFFICER]/a director] of the Company/alleged actions or failures to act in my capacity as [an officer/[TITLE OF OFFICER]/a director] of the Company.] This undertaking also constitutes notice to the Company of the Proceeding pursuant to Section 7 of the Indemnification Agreement. The following is a brief description of the [current status of the] Proceeding:

[DESCRIPTION OF PROCEEDING]

Pursuant to Section 4 of the Indemnification Agreement, the Company can (a) pay such Expenses on my behalf, (b) advance funds in an amount sufficient to pay such Expenses, or (c) reimburse me for such Expenses. Pursuant to Section 4 of the Indemnification Agreement, I hereby request an Expense Advance in connection with the Proceeding. The Expenses for which advances are requested are as follows:

[DESCRIPTION OF EXPENSES]

In connection with the request for Expense Advances [set out above/delivered to the Company separately on [DATE]],I hereby undertake to repay any amounts paid, advanced or reimbursed by the Company for such Expense Advances to the extent that it is ultimately determined that I am not entitled to indemnification under the Indemnification Agreement.

A-2

This undertaking shall be governed by and construed in accordance with the laws of the State of Delaware, without regard to the principles of conflicts of laws thereof.

[SIGNATURE PAGE FOLLOWS]

Very truly yours,

________________

Name:

[Title:]

[cc: [ADD PARTY NAME AND ADDRESS AS REQUIRED]]

A-2

EX-31.1

Exhibit 31.1

CERTIFICATIONS

I, Robert G. Phillips, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date: August 6, 2020

/s/ Robert G. Phillips

Robert G. Phillips

Chairman, President and Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATIONS

I, Robert T. Halpin, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date: August 6, 2020

/s/ Robert T. Halpin

Robert T. Halpin

Executive Vice President and Chief Financial Officer

EX-31.3

Exhibit 31.3

CERTIFICATIONS

I, Robert G. Phillips, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date: August 6, 2020

/s/ Robert G. Phillips

Robert G. Phillips

Chairman, President and Chief Executive Officer

EX-31.4

Exhibit 31.4

CERTIFICATIONS

I, Robert T. Halpin, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date: August 6, 2020

/s/ Robert T. Halpin    

Robert T. Halpin

Executive Vice President and Chief Financial Officer

EX-32.1

Exhibit 32.1

Certification of the Chief Executive Officer

Pursuant to 18 U.S.C. Section 1350

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

In connection with the Quarterly Report of Crestwood Equity Partners LP (the “Company”) on Form 10-Q for the period ended June 30, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert G. Phillips, Chief Executive Officer of Crestwood Equity Partners LP, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

	/s/ Robert G. Phillips
August 6, 2020	Robert G. Phillips Chief Executive Officer

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

EX-32.2

Exhibit 32.2

Certification of the Chief Financial Officer

Pursuant to 18 U.S.C. Section 1350

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

In connection with the Quarterly Report of Crestwood Equity Partners LP (the “Company”) on Form 10-Q for the period ended June 30, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert T. Halpin, Chief Financial Officer of Crestwood Equity Partners LP, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

	/s/ Robert T. Halpin
August 6, 2020	Robert T. Halpin Chief Financial Officer

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

EX-32.3

Exhibit 32.3

Certification of the Chief Executive Officer

Pursuant to 18 U.S.C. Section 1350

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

In connection with the Quarterly Report of Crestwood Midstream Partners LP (the “Company”) on Form 10-Q for the period ended June 30, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert G. Phillips, Chief Executive Officer of Crestwood Midstream Partners LP, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

	/s/ Robert G. Phillips
August 6, 2020	Robert G. Phillips Chief Executive Officer

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

EX-32.4

Exhibit 32.4

Certification of the Chief Financial Officer

Pursuant to 18 U.S.C. Section 1350

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

In connection with the Quarterly Report of Crestwood Midstream Partners LP (the “Company”) on Form 10-Q for the period ended June 30, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert T. Halpin, Chief Financial Officer of Crestwood Midstream Partners LP, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

	/s/ Robert T. Halpin
August 6, 2020	Robert T. Halpin Chief Financial Officer

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

XML

Cover Page - shares	6 Months Ended
	Jun. 30, 2020	Jul. 31, 2020
Document Information [Line Items]
Document Transition Report	false
Document Quarterly Report	true
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity Current Reporting Status	Yes
Entity Address, Address Line One	811 Main Street
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2020
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q2
Entity Registrant Name	Crestwood Equity Partners LP
Entity File Number	001-34664
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	43-1918951
Entity Central Index Key	0001136352
Current Fiscal Year End Date	--12-31
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		73,161,478
Entity Address, Address Line Two	Suite 3400
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	832
Local Phone Number	519-2200
Crestwood Midstream Partners LP
Document Information [Line Items]
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity Current Reporting Status	Yes
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2020
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q2
Entity Registrant Name	Crestwood Midstream Partners LP
Entity File Number	001-35377
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	20-1647837
Entity Central Index Key	0001304464
Current Fiscal Year End Date	--12-31
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		0
Common Units
Document Information [Line Items]
Title of 12(b) Security	Common Units representing limited partnership interests
Trading Symbol	CEQP
Security Exchange Name	NYSE
Preferred Units
Document Information [Line Items]
Title of 12(b) Security	Preferred Units representing limited partnership interests
Trading Symbol	CEQP-P
Security Exchange Name	NYSE

XML

Consolidated Balance Sheets - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Assets
Cash	$ 6.7	$ 25.7
Accounts receivable, less allowance for doubtful accounts of $0.6 million and $0.3 million at June 30, 2020 and December 31, 2019	165.9	242.2
Inventory	88.9	53.7
Assets from price risk management activities	44.4	43.2
Prepaid expenses and other current assets	8.7	11.6
Total current assets	314.6	376.4
Property, plant and equipment	3,829.2	3,612.5
Less: accumulated depreciation	786.8	703.4
Property, plant and equipment, net	3,042.4	2,909.1
Intangible assets	1,118.1	1,076.3
Less: accumulated amortization	301.0	271.1
Intangible assets, net	817.1	805.2
Goodwill	138.6	218.9
Operating lease, right-of-use assets, net	44.2	53.8
Investments in unconsolidated affiliates	961.9	980.4
Other non-current assets	4.9	5.5
Total assets	5,323.7	5,349.3
Current liabilities:
Accounts payable	118.6	189.2
Accrued expenses and other liabilities	133.8	161.7
Liabilities from price risk management activities	32.2	6.7
Current portion of long-term debt	0.2	0.2
Total current liabilities	284.8	357.8
Long-term debt, less current portion	2,575.7	2,328.3
Other long-term liabilities	285.7	301.6
Deferred income taxes	2.3	2.6
Total liabilities	3,148.5	2,990.3
Commitments and contingencies (Note 11)
Interest of non-controlling partner in subsidiary	430.6	426.2
Partners’ capital:
Crestwood Equity Partners LP partners’ capital (73,605,008 and 72,282,942 common and subordinated units issued and outstanding at June 30, 2020 and December 31, 2019)	1,132.6	1,320.8
Preferred units (71,257,445 units issued and outstanding at both June 30, 2020 and December 31, 2019)	612.0	612.0
Total partners’ capital	1,744.6	1,932.8
Total liabilities and capital	5,323.7	5,349.3
Crestwood Midstream Partners LP
Assets
Cash	6.1	25.4
Accounts receivable, less allowance for doubtful accounts of $0.6 million and $0.3 million at June 30, 2020 and December 31, 2019	165.8	241.9
Inventory	88.9	53.7
Assets from price risk management activities	44.4	43.2
Prepaid expenses and other current assets	8.7	11.6
Total current assets	313.9	375.8
Property, plant and equipment	4,159.2	3,942.6
Less: accumulated depreciation	965.5	875.1
Property, plant and equipment, net	3,193.7	3,067.5
Intangible assets	1,118.1	1,076.3
Less: accumulated amortization	301.0	271.1
Intangible assets, net	817.1	805.2
Goodwill	138.6	218.9
Operating lease, right-of-use assets, net	44.2	53.8
Investments in unconsolidated affiliates	961.9	980.4
Other non-current assets	2.9	2.4
Total assets	5,472.3	5,504.0
Current liabilities:
Accounts payable	116.1	186.6
Accrued expenses and other liabilities	132.4	160.4
Liabilities from price risk management activities	32.2	6.7
Current portion of long-term debt	0.2	0.2
Total current liabilities	280.9	353.9
Long-term debt, less current portion	2,575.7	2,328.3
Other long-term liabilities	284.0	295.6
Deferred income taxes	0.6	0.7
Total liabilities	3,141.2	2,978.5
Interest of non-controlling partner in subsidiary	430.6
Partners’ capital:
Partners' capital	1,900.5	2,099.3
Interest of non-controlling partner in subsidiary (Note 10)		426.2
Total liabilities and capital	$ 5,472.3	$ 5,504.0

XML

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Allowance for doubtful accounts	$ 0.6	$ 0.3
Limited Partners' Capital Account, Units Issued	73,605,008	72,282,942
Limited Partners' Capital Account, Units Outstanding	73,605,008	72,282,942
Preferred Units, Issued	71,257,445	71,257,445
Preferred Units, Outstanding	71,257,445	71,257,445
Crestwood Midstream Partners LP
Allowance for doubtful accounts	$ 0.6	$ 0.3

XML

Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Revenues:
Revenues	$ 352.7	$ 683.4	$ 1,080.6	$ 1,518.6
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 12)	3.6	0.9	6.8	35.3
Total costs of product/services sold	225.7	537.2	760.1	1,232.8
Operating expenses and other:
Operations and maintenance	31.6	34.7	69.2	63.3
General and administrative	29.5	22.3	44.4	59.5
Depreciation, amortization and accretion	61.0	49.3	117.1	89.1
Loss on long-lived assets, net	3.8	0.0	4.8	2.0
Goodwill impairment	0.0	0.0	80.3	0.0
Gain on acquisition	0.0	(209.4)	0.0	(209.4)
Total expenses	125.9	(103.1)	315.8	4.5
Operating income (loss)	1.1	249.3	4.7	281.3
Earnings from unconsolidated affiliates, net	8.4	3.7	13.9	10.6
Interest and debt expense, net	(34.0)	(27.8)	(66.6)	(52.7)
Other income, net	0.1	0.1	0.2	0.2
Income (loss) before income taxes	(24.4)	225.3	(47.8)	239.4
(Provision) benefit for income taxes	(0.1)	0.3	(0.1)	0.3
Net income (loss)	(24.3)	225.0	(47.7)	239.1
Net income attributable to non-controlling partner	10.2	10.6	20.1	14.6
Net income (loss) attributable to parent	(34.5)	214.4	(67.8)	224.5
Net income attributable to preferred unit holders	15.0	15.0	30.0	30.0
Net income (loss) attributable to partners	(49.5)	199.4	(97.8)	194.5
Subordinated unitholders’ interest in net income	0.0	1.2	0.0	1.2
Common unitholders’ interest in net income (loss)	$ (49.5)	$ 198.2	$ (97.8)	$ 193.3
Net income (loss) per limited partner unit:
Basic (in dollars per share)	$ (0.68)	$ 2.76	$ (1.34)	$ 2.69
Diluted (in dollars per share)	$ (0.68)	$ 2.58	$ (1.34)	$ 2.53
Weighted-average limited partners’ units outstanding:
Basic (units)	73.2	71.8	73.0	71.8
Dilutive units (units)	0.0	11.2	0.0	5.2
Diluted (units)	73.2	83.0	73.0	77.0
Crestwood Midstream Partners LP
Revenues:
Revenues	$ 352.7	$ 683.4	$ 1,080.6	$ 1,518.6
Related party (Note 12)	0.1	0.0	0.3	0.0
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 12)	3.6	0.9	6.8	35.3
Total costs of product/services sold	225.7	537.2	760.1	1,232.8
Operating expenses and other:
Operations and maintenance	31.6	34.7	69.2	63.3
General and administrative	28.4	20.9	41.9	56.9
Depreciation, amortization and accretion	64.6	52.7	124.2	96.1
Loss on long-lived assets, net	3.8	0.0	4.8	2.0
Goodwill impairment	0.0	0.0	80.3	0.0
Gain on acquisition	0.0	(209.4)	0.0	(209.4)
Total expenses	128.4	(101.1)	320.4	8.9
Operating income (loss)	(1.4)	247.3	0.1	276.9
Earnings from unconsolidated affiliates, net	8.4	3.7	13.9	10.6
Interest and debt expense, net	(34.0)	(27.8)	(66.6)	(52.7)
Income (loss) before income taxes	(27.0)	223.2	(52.6)	234.8
(Provision) benefit for income taxes	(0.2)	0.3	(0.2)	0.3
Net income (loss)	(26.8)	222.9	(52.4)	234.5
Net income attributable to non-controlling partner	10.2	10.6	20.1	14.6
Net income (loss) attributable to parent	(37.0)	212.3	(72.5)	219.9
Product
Revenues:
Revenues	258.4	579.6	864.9	1,327.2
Related party (Note 12)	7.4	1.3	14.7	2.5
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	217.4	529.5	742.0	1,183.0
Product | Crestwood Midstream Partners LP
Revenues:
Revenues	258.4	579.6	864.9	1,327.2
Related party (Note 12)	7.4	1.3	14.7	2.5
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	217.4	529.5	742.0	1,183.0
Service
Revenues:
Revenues	94.3	103.8	215.7	191.4
Related party (Note 12)	0.1	0.0	0.3	0.0
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	4.7	6.8	11.3	14.5
Service | Crestwood Midstream Partners LP
Revenues:
Revenues	94.3	103.8	215.7	191.4
Costs of product/services sold (exclusive of items shown separately below):
Costs of product/services sold	4.7	6.8	11.3	14.5
Gathering and Processing Segment | Product
Revenues:
Revenues	30.5	106.2	133.2	215.8
Gathering and Processing Segment | Product | Crestwood Midstream Partners LP
Revenues:
Revenues	30.5	106.2	133.2	215.8
Gathering and Processing Segment | Service
Revenues:
Revenues	84.0	93.5	196.2	166.2
Gathering and Processing Segment | Service | Crestwood Midstream Partners LP
Revenues:
Revenues	84.0	93.5	196.2	166.2
Marketing Supply and Logistics
Revenues:
Revenues				1,123.9
Marketing Supply and Logistics | Product
Revenues:
Revenues	220.5	472.1	717.0	1,108.9
Marketing Supply and Logistics | Product | Crestwood Midstream Partners LP
Revenues:
Revenues	220.5	472.1	717.0	1,108.9
Marketing Supply and Logistics | Service
Revenues:
Revenues	7.1	5.4	12.6	12.5
Marketing Supply and Logistics | Service | Crestwood Midstream Partners LP
Revenues:
Revenues	7.1	5.4	12.6	12.5
Storage and Transportation | Service
Revenues:
Revenues	3.1	4.9	6.6	12.7
Storage and Transportation | Service | Crestwood Midstream Partners LP
Revenues:
Revenues	$ 3.1	$ 4.9	$ 6.6	$ 12.7

XML

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ (24.3)	$ 225.0	$ (47.7)	$ 239.1
Change in fair value of Suburban Propane Partners, L.P. units	0.0	0.3	(1.1)	0.7
Comprehensive income (loss)	(24.3)	225.3	(48.8)	239.8
Comprehensive income attributable to non-controlling partner	10.2	10.6	20.1	14.6
Comprehensive income (loss) attributable to Crestwood Equity Partners LP	$ (34.5)	$ 214.7	$ (68.9)	$ 225.2

XML

Consolidated Statement of Partners' Capital - USD ($) $ in Millions	Total	Preferred Units	Common unit	Non-Controlling Partners	Partners' Capital	Crestwood Midstream Partners LP	Crestwood Midstream Partners LP Common unit	Crestwood Midstream Partners LP Non-Controlling Partners	Crestwood Midstream Partners LP Partners' Capital	Preferred Units	Common Units	Subordinated Units
Increase (Decrease) in Partners' Capital [Roll Forward]
Common Unit, Outstanding											71,200,000	400,000
Preferred Units, Outstanding										71,300,000
Beginning balance at Dec. 31, 2018		$ 612.0	$ 1,240.5	$ 181.3	$ 2,033.8		$ 2,028.2	$ 181.3	$ 2,209.5
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(15.0)	(43.1)	(3.3)	(61.4)		(57.8)	(3.3)	(61.1)
Unit-based compensation charges			17.3		17.3		17.3		17.3
Unit-based compensation charges (in shares)											900,000
Taxes paid for unit-based compensation vesting			(7.0)		(7.0)		(7.0)		(7.0)
Taxes paid for unit-based compensation vesting (in shares)											(200,000)
Change in fair value of Suburban Propane Partners, L.P. units			0.4		0.4
Other			(0.7)		(0.7)		(0.3)		(0.3)
Net income (loss)		15.0	(4.9)	4.0	14.1		7.6	4.0	11.6
Ending Balance at Mar. 31, 2019		612.0	1,202.5	182.0	1,996.5		1,988.0	182.0	2,170.0
Beginning balance at Dec. 31, 2018		612.0	1,240.5	181.3	2,033.8		2,028.2	181.3	2,209.5
Increase (Decrease) in Partners' Capital [Roll Forward]
Non-controlling interest reclassification (Note 10)	$ 178.8
Change in fair value of Suburban Propane Partners, L.P. units	0.7
Net income (loss)	239.1					$ 234.5
Ending Balance at Jun. 30, 2019		612.0	1,366.4	0.0	1,978.4		2,148.2	0.0	2,148.2
Increase (Decrease) in Partners' Capital [Roll Forward]
Common Unit, Outstanding											71,900,000	400,000
Preferred Units, Outstanding										71,300,000
Beginning balance at Mar. 31, 2019		612.0	1,202.5	182.0	1,996.5		1,988.0	182.0	2,170.0
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(15.0)	(43.1)	(3.3)	(61.4)		(59.7)	(3.3)	(63.0)
Unit-based compensation charges			11.3		11.3		11.3		11.3
Taxes paid for unit-based compensation vesting			(3.6)		(3.6)		(3.6)		(3.6)
Non-controlling interest reclassification (Note 10)				(178.8)	(178.8)			(178.8)	(178.8)
Taxes paid for unit-based compensation vesting (in shares)											(100,000)
Change in fair value of Suburban Propane Partners, L.P. units	0.3		0.3		0.3
Other			(0.4)	0.1	(0.3)		(0.1)	0.1	0.0
Net income (loss)	$ 225.0	15.0	199.4	0.0	214.4	222.9	212.3	0.0	212.3
Ending Balance at Jun. 30, 2019		612.0	1,366.4	$ 0.0	1,978.4		$ 2,148.2	$ 0.0	2,148.2
Increase (Decrease) in Partners' Capital [Roll Forward]
Common Unit, Outstanding											71,800,000	400,000
Preferred Units, Outstanding										71,300,000
Common Unit, Outstanding											71,900,000	400,000
Preferred Units, Outstanding	71,257,445									71,300,000
Beginning balance at Dec. 31, 2019		612.0	1,320.8		1,932.8	2,099.3			2,099.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(15.0)	(45.3)		(60.3)				(57.0)
Unit-based compensation charges			0.2		0.2				(4.4)
Unit-based compensation charges (in shares)											1,700,000
Taxes paid for unit-based compensation vesting			(15.1)		(15.1)				(15.1)
Taxes paid for unit-based compensation vesting (in shares)											(500,000)
Change in fair value of Suburban Propane Partners, L.P. units			(1.1)		(1.1)
Other			3.5		3.5				(1.1)
Net income (loss)		15.0	(48.3)		(33.3)				(35.5)
Ending Balance at Mar. 31, 2020		612.0	1,214.7		1,826.7				1,986.2
Beginning balance at Dec. 31, 2019		612.0	1,320.8		1,932.8	2,099.3			2,099.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Change in fair value of Suburban Propane Partners, L.P. units	$ (1.1)
Net income (loss)	(47.7)					(52.4)
Ending Balance at Jun. 30, 2020		612.0	1,132.6		1,744.6	1,900.5			1,900.5
Increase (Decrease) in Partners' Capital [Roll Forward]
Common Unit, Outstanding											73,300,000	400,000
Preferred Units, Outstanding										71,300,000
Other (in shares)											200,000
Beginning balance at Mar. 31, 2020		612.0	1,214.7		1,826.7				1,986.2
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(15.0)	(45.7)		(60.7)				(62.0)
Unit-based compensation charges			13.6		13.6				13.6
Unit-based compensation charges (in shares)											0
Taxes paid for unit-based compensation vesting			(0.4)		(0.4)				(0.4)
Taxes paid for unit-based compensation vesting (in shares)											(100,000)
Change in fair value of Suburban Propane Partners, L.P. units	0.0
Other			(0.1)		(0.1)				0.1
Net income (loss)	$ (24.3)	15.0	(49.5)		(34.5)	(26.8)			(37.0)
Ending Balance at Jun. 30, 2020		$ 612.0	$ 1,132.6		$ 1,744.6	$ 1,900.5			$ 1,900.5
Increase (Decrease) in Partners' Capital [Roll Forward]
Common Unit, Outstanding											73,200,000	400,000
Preferred Units, Outstanding	71,257,445									71,300,000
Other (in shares)											0

XML

Consolidated Statements of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Operating activities
Net income (loss)	$ (47.7)	$ 239.1
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	117.1	89.1
Amortization of debt-related deferred costs	3.2	2.9
Unit-based compensation charges	9.2	28.6
Loss on long-lived assets, net	4.8	2.0
Gain on acquisition	0.0	(209.4)
Goodwill impairment	80.3	0.0
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	5.4	6.3
Deferred income taxes	(0.3)	0.3
Changes in operating assets and liabilities	11.4	35.0
Net cash provided by operating activities	183.4	193.9
Investing activities
Acquisitions, net of cash acquired (Note 3)	162.3	462.1
Purchases of property, plant and equipment	(143.2)	(204.7)
Investments in unconsolidated affiliates	(6.0)	(40.9)
Capital distributions from unconsolidated affiliates	18.9	24.2
Other	(0.3)	(0.5)
Net cash used in investing activities	(292.9)	(684.0)
Financing activities
Proceeds from the issuance of long-term debt	742.5	1,544.0
Payments on long-term debt	(498.2)	(1,159.5)
Payments on finance leases	(1.6)	(1.9)
Payments for debt-related deferred costs	0.0	(9.0)
Net proceeds from issuance of non-controlling interest	2.8	235.0
Distributions to partners	(91.0)	(86.2)
Distributions to non-controlling partner	18.5	6.6
Distributions to preferred unitholders	30.0	30.0
Taxes paid for unit-based compensation vesting	(15.5)	(10.6)
Other	0.0	(0.2)
Net cash provided by financing activities	90.5	475.0
Net change in cash	(19.0)	(15.1)
Cash at beginning of period	25.7	17.2
Cash at end of period	6.7	2.1
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	35.9	(22.2)
Crestwood Midstream Partners LP
Operating activities
Net income (loss)	(52.4)	234.5
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	124.2	96.1
Amortization of debt-related deferred costs	3.2	2.9
Unit-based compensation charges	9.2	28.6
Loss on long-lived assets, net	4.8	2.0
Gain on acquisition	0.0	(209.4)
Goodwill impairment	80.3	0.0
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	5.4	6.3
Deferred income taxes	(0.1)	0.2
Changes in operating assets and liabilities	6.5	33.9
Net cash provided by operating activities	181.1	195.1
Investing activities
Acquisitions, net of cash acquired (Note 3)	162.3	462.1
Purchases of property, plant and equipment	(143.2)	(204.7)
Investments in unconsolidated affiliates	(6.0)	(40.9)
Capital distributions from unconsolidated affiliates	18.9	24.2
Other	(0.3)	(0.5)
Net cash used in investing activities	(292.9)	(684.0)
Financing activities
Proceeds from the issuance of long-term debt	742.5	1,544.0
Payments on long-term debt	(498.2)	(1,159.5)
Payments on finance leases	(1.6)	(1.9)
Payments for debt-related deferred costs	0.0	(9.0)
Net proceeds from issuance of non-controlling interest	2.8	235.0
Distributions to partners	(119.0)	(117.5)
Distributions to non-controlling partner	18.5	6.6
Taxes paid for unit-based compensation vesting	(15.5)	(10.6)
Net cash provided by financing activities	92.5	473.9
Net change in cash	(19.3)	(15.0)
Cash at beginning of period	25.4	16.5
Cash at end of period	6.1	1.5
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	35.9	$ (22.2)
Non-Controlling Partners
Financing activities
Net proceeds from issuance of non-controlling interest	$ 2.8

XML

Organization and Business Description

6 Months Ended

Jun. 30, 2020

Disclosure Partnership Organization And Basis Of Presentation Narrative [Abstract]

Organization and Business Description

Organization and Business Description

Organization

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

The accompanying consolidated financial statements and related notes should be read in conjunction with our 2019 Annual Report on Form 10-K filed with the Securities and Exchange Commission (SEC) on February 21, 2020. The financial information as of June 30, 2020, and for the three and six months ended June 30, 2020 and 2019, is unaudited. The consolidated balance sheets as of December 31, 2019, were derived from the audited balance sheets filed in our 2019 Annual Report on Form 10-K.

Business Description

Crestwood Equity is a publicly-traded Delaware limited partnership that develops, acquires, owns or controls, and operates primarily fee-based assets and operations within the energy midstream sector. We provide broad-ranging infrastructure solutions across the value chain to service premier liquids-rich natural gas and crude oil shale plays across the United States. We own and operate a diversified portfolio of crude oil and natural gas gathering, processing, storage 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, a Delaware limited partnership.

XML

Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2020

Accounting Policies [Abstract]

Basis of Presentation and Significant Accounting Policies

Basis of Presentation and Summary of Significant Accounting Policies

Basis of Presentation

Our consolidated financial statements are prepared in accordance with Generally Accepted Accounting Principles (GAAP) and include the accounts of all consolidated subsidiaries after the elimination of all intercompany accounts and transactions. In management’s opinion, all necessary adjustments to fairly present our results of operations, financial position and cash flows for the periods presented have been made and all such adjustments are of a normal and recurring nature. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.

Significant Accounting Policies

There were no material changes in our significant accounting policies from those described in our 2019 Annual Report on Form 10-K. Below is an update of our accounting policies related to Goodwill and Accounts Receivable.

Goodwill

Our goodwill represents the excess of the amount we paid for a business over the fair value of the net identifiable assets acquired. We evaluate goodwill for impairment annually on December 31, and whenever events indicate that it is more likely than not that the fair value of a reporting unit could be less than its carrying amount. This evaluation requires us to compare the fair value of each of our reporting units to its carrying value (including goodwill). If the fair value exceeds the carrying amount, goodwill of the reporting unit is not considered impaired.

We estimate the fair value of our reporting units based on a number of factors, including discount rates, projected cash flows and the potential value we would receive if we sold the reporting unit. Estimating projected cash flows requires us to make

certain assumptions as it relates to the future operating performance of each of our reporting units (which includes assumptions, among others, about estimating future operating margins and related future growth in those margins, contracting efforts and the cost and timing of facility expansions) and assumptions related to our customers, such as their future capital and operating plans and their financial condition. When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. If the assumptions embodied in the projections prove inaccurate, we could incur a future impairment charge. In addition, the use of the income approach to determine the fair value of our reporting units (see further discussion of the use of the income approach below) could result in a different fair value if we had utilized a market approach, or a combination thereof.

The following table summarizes the goodwill of our various reporting units (in millions):

			Impairment during the six months ended
	December 31, 2019		June 30, 2020		June 30, 2020
Gathering and Processing
Arrow	$	45.9	$	—	$	45.9
Powder River Basin	80.3		80.3		—
Marketing, Supply and Logistics
NGL Marketing and Logistics	92.7		—		92.7
Total	$	218.9	$	80.3	$	138.6

During the first quarter of 2020, current and forward commodity prices significantly declined from their levels at December 31, 2019 due primarily to the decreases in energy demand as a result of the outbreak of the COVID-19 pandemic and actions taken by the Organization of the Petroleum Exporting Countries, Russia, the United States and other oil-producing countries relating to the oversupply of oil. We currently anticipate that the decrease in commodity prices will have a negative impact on certain of our customers in our gathering and processing segment, which could adversely impact the financial performance of certain of the reporting units within those operations.

Upon acquisition, we are required to record the assets, liabilities and goodwill of a reporting unit at its fair value on the date of acquisition. As a result, any level of decrease in the forecasted cash flows of these businesses or increases in the discount rates utilized to value those businesses from their respective acquisition dates would likely result in the fair value of the reporting unit falling below the carrying value of the reporting unit, and could result in an assessment of whether that reporting unit's goodwill is impaired.

We acquired our Powder River Basin reporting unit in 2019 and recorded it at fair value at that time. Based on the events that occurred during the first quarter of 2020 described above, we determined that the forecasted cash flows, and therefore the fair value, of our Powder River Basin reporting unit significantly decreased during the first quarter of 2020, and accordingly performed a quantitative impairment assessment of the goodwill related to that reporting unit during that period. Based on our quantitative assessment, which utilized the income approach, we determined that the goodwill associated with the Powder River Basin reporting unit should be fully impaired during the first quarter of 2020, and accordingly recorded an $80.3 million impairment of the goodwill attributed to that reporting unit during the first quarter of 2020. We did not record any impairments of the goodwill associated with our Arrow or NGL Marketing and Logistics reporting units during the six months ended June 30, 2020, as we do not have indicators that it is more likely than not that the fair value of those reporting units has declined to below their carrying value at June 30, 2020.

Accounts Receivable

Effective January 1, 2020, we adopted the provision of Accounting Standards Update 2016-13, Financial Instruments - Credit Losses (Topic 326), which provides revised guidance on evaluating accounts and notes receivable and other financial instruments for impairment. We record accounts receivable when products or services are delivered and it is probable that payment will be received for those products or services, and we do not record any interest or penalties on accounts receivable that are past due under the terms of the related arrangement or invoice until those amounts are received. Topic 326 requires companies to evaluate their financial instruments for impairment by recording an allowance for doubtful accounts and/or bad debt expense based on certain categories of instruments rather than a specific identification approach. We adopted the

provisions of this standard using a method to estimate the allowance for doubtful accounts that considered both the aging of our accounts receivable and the projected loss rate of our receivables. We write off accounts receivable, and the related allowance for doubtful accounts, when it becomes remote that payment for products or services will be received. On January 1, 2020, we recorded a $0.7 million increase to our allowance for doubtful accounts and a $0.7 million decrease to partners’ capital to reflect the cumulative effect of adopting the new standard. In addition, on January 1, 2020, Crestwood Permian Basin Holdings LLC (Crestwood Permian), our 50% equity investment, also adopted the provisions of Topic 326 and we recorded a decrease of approximately $0.2 million to our equity investment and a corresponding decrease to our partners’ capital to reflect our proportionate share of the cumulative effect of accounting change recorded by the equity investment related to the new standard. The adoption of this standard was not material to our other equity investments.

XML

Acquisitions

6 Months Ended

Jun. 30, 2020

Business Combinations [Abstract]

Acquisitions

Acquisitions

NGL Asset Acquisition

In April 2020, we acquired several NGL storage and rail-to-truck liquid petroleum gas (LPG) terminals from Plains All American Pipeline, L.P. (Plains) for approximately $162 million. The acquired assets include 7 MMBbls of NGL storage and seven LPG terminals, and resulted in an increase of approximately $160 million in our property, plant and equipment and intangible assets and an increase of approximately $2 million to our other assets and liabilities, net during the three months ended June 30, 2020. We allocated the purchase price to these assets and liabilities based on their fair values, which are Level 3 fair value measurements and were developed by management with the assistance of a third-party valuation firm utilizing market-related information about the property, plant and equipment and customer relationships acquired. These assets are included in our marketing, supply and logistics segment. The transaction costs related to this acquisition were not material for the three and six months ended June 30, 2020.

Jackalope Acquisition

On April 9, 2019, Crestwood Niobrara LLC (Crestwood Niobrara), our consolidated subsidiary, acquired Williams Partners LP’s (Williams) 50% equity interest in Jackalope Gas Gathering Services, L.L.C. (Jackalope) for approximately $484.6 million (Jackalope Acquisition). The acquisition was funded through a combination of borrowings under the CMLP credit facility and the issuance of $235 million of new preferred units to CN Jackalope Holdings LLC (Jackalope Holdings) (see Note 10 for a further discussion of the issuance of the new preferred units). Prior to the Jackalope Acquisition, Crestwood Niobrara owned a 50% equity interest in Jackalope, which we accounted for under the equity method of accounting. As a result of this transaction, Crestwood Niobrara controls and owns 100% of the equity interests in Jackalope. The financial results of Jackalope are included in our gathering and processing segment from the date of the acquisition.

The fair value of the assets acquired and liabilities assumed in the Jackalope Acquisition exceeded the sum of the cash consideration paid and the historical book value of our 50% equity interest in Jackalope (which was remeasured at fair value and derecognized) and, as a result, we recognized a gain of approximately $209.4 million. This gain is included in gain on acquisition in our consolidated statements of operations.

XML

Certain Balance Sheet Information

6 Months Ended

Jun. 30, 2020

Balance Sheet Related Disclosures [Abstract]

Certain Balance Sheet Information

Certain Balance Sheet Information

Accrued Expenses and Other Liabilities

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

	CEQP				CMLP
	June 30,		December 31,		June 30,		December 31,
	2020		2019		2020		2019
Accrued expenses	$	35.1	$	61.6	$	33.7	$	60.3
Accrued property taxes	8.2		6.1		8.2		6.1
Income tax payable	0.3		0.3		0.3		0.3
Interest payable	25.0		25.6		25.0		25.6
Accrued additions to property, plant and equipment	14.9		38.0		14.9		38.0
Contingent consideration	19.0		—		19.0		—
Operating leases	17.8		18.1		17.8		18.1
Finance leases	3.3		3.2		3.3		3.2
Deferred revenue	10.2		8.8		10.2		8.8
Total accrued expenses and other liabilities	$	133.8	$	161.7	$	132.4	$	160.4

Other Long-Term Liabilities

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

	CEQP				CMLP
	June 30,		December 31,		June 30,		December 31,
	2020		2019		2020		2019
Contract liabilities	$	159.6	$	144.7	$	159.6	$	144.7
Contingent consideration	38.0		57.0		38.0		57.0
Operating leases	32.9		41.5		32.9		41.5
Asset retirement obligations	34.6		33.3		34.6		33.3
Other	20.6		25.1		18.9		19.1
Total other long-term liabilities	$	285.7	$	301.6	$	284.0	$	295.6

XML

Investments in Unconsolidated Affiliates

6 Months Ended

Jun. 30, 2020

Equity Method Investments and Joint Ventures [Abstract]

Investments in Unconsolidated Affiliates

Investments in Unconsolidated Affiliates

Variable Interest Entity

Crestwood Permian is a joint venture owned by Crestwood Infrastructure Holdings LLC (Crestwood Infrastructure), our wholly-owned subsidiary, and an affiliate of First Reserve Management, L.P. (First Reserve). We manage and account for our 50% ownership interest in Crestwood Permian, which is a variable interest entity, under the equity method of accounting as we exercise significant influence, but do not control Crestwood Permian and we are not its primary beneficiary due to First Reserve’s rights to exercise control over the entity.

Net Investments and Earnings

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

	Investment				Earnings (Loss) from Unconsolidated Affiliates						Earnings (Loss) from Unconsolidated Affiliates
	June 30,		December 31,		Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		2020			2019			2020			2019
Stagecoach Gas Services LLC(1)	$	802.8	$	814.4	$	9.2		$	6.4		$	18.4		$	13.4
Crestwood Permian Basin Holdings LLC(2)	114.7		121.8		(1.0		)	(3.3		)	(0.2		)	(6.7		)
Tres Palacios Holdings LLC(3)	40.6		35.9		0.1			0.1			0.1			0.3
Powder River Basin Industrial Complex, LLC(4)	3.8		8.3		0.1			—			(4.4		)	(0.1		)
Jackalope Gas Gathering Services, L.L.C.(5)	—		—		—			0.5			—			3.7
Total	$	961.9	$	980.4	$	8.4		$	3.7		$	13.9		$	10.6

(1) As of June 30, 2020, our equity in the underlying net assets of Stagecoach Gas Services LLC (Stagecoach Gas) exceeded our investment balance by approximately $51.3 million. This excess amount is entirely attributable to goodwill and, as such, is not subject to amortization. Our Stagecoach Gas investment is included in our storage and transportation segment.

(2) As of June 30, 2020, our equity in the underlying net assets of Crestwood Permian exceeded our investment balance by $9.7 million, and this excess amount is not subject to amortization. Our Crestwood Permian investment is included in our gathering and processing segment.

(3) As of June 30, 2020, our equity in the underlying net assets of Tres Palacios Holdings LLC (Tres Holdings) exceeded our investment balance by approximately $23.4 million. Our Tres Holdings investment is included in our storage and transportation segment.

(4) As of June 30, 2020, our equity in the underlying net assets of Powder River Basin Industrial Complex, LLC (PRBIC) approximates our investment balance. During the first quarter of 2020, we recorded our share of a long-lived asset impairment recorded by our PRBIC equity investment, which eliminated our $5.5 million historical basis difference between our investment balance and the equity in the underlying net assets of PRBIC, and also resulted in a $4.5 million reduction in our earnings from unconsolidated affiliates during the six months ended June 30, 2020. Our PRBIC investment is included in our storage and transportation segment.

(5) On April 9, 2019, Crestwood Niobrara acquired Williams 50% equity interest in Jackalope, and as a result, Crestwood Niobrara controls and owns 100% of the equity interests in Jackalope. As a result of this transaction, we eliminated our historical equity investment in Jackalope and began consolidating Jackalope’s operations. Our Jackalope investment was included in our gathering and processing segment.

Summarized Financial Information of Unconsolidated Affiliates

Below is the summarized operating results for our significant unconsolidated affiliates (in millions; amounts represent 100% of unconsolidated affiliate information):

	Six Months Ended June 30,
	2020							2019
	Operating Revenues		Operating Expenses		Net Income (Loss)			Operating Revenues		Operating Expenses		Net Income (Loss)
Stagecoach Gas	$	75.6	$	38.9	$	36.8		$	79.1	$	40.4	$	38.9
Other(1)	53.5		76.1		(21.6		)	55.4		62.2		(7.9		)
Total	$	129.1	$	115.0	$	15.2		$	134.5	$	102.6	$	31.0

(1) Includes our Crestwood Permian, Tres Holdings and PRBIC equity investments during the six months ended June 30, 2020 and 2019, and our Jackalope equity investment during the six months ended June 30, 2019 (prior to the acquisition of the remaining 50% equity interest from Williams in April 2019). We amortize the excess basis in certain of our equity investments as an increase in our earnings from unconsolidated affiliates. We recorded amortization of the excess basis in our Tres Holdings equity investment of $0.6 million during both the six months ended June 30, 2020 and 2019. We recorded amortization of the excess basis in our PRBIC equity investment of $0.2 million during the six months ended June 30, 2019. We recorded amortization of the excess basis in the Jackalope equity investment of less than $0.1 million during the six months ended June 30, 2019.

Distributions and Contributions

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

	Distributions(1)				Contributions
	Six Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
Stagecoach Gas	$	30.0	$	25.4	$	—	$	—
Crestwood Permian	6.7		2.9		—		10.0
Tres Holdings	1.4		1.2		6.0		6.3
PRBIC	0.1		—		—		0.2
Jackalope	—		11.6		—		24.4
Total	$	38.2	$	41.1	$	6.0	$	40.9

(1) In July 2020, we received cash distributions from Stagecoach Gas, Crestwood Permian and Tres Holdings of approximately $14.5 million, $1.8 million and $3.0 million, respectively.

Other

Contingent Consideration. Pursuant to the Stagecoach Gas limited liability company agreement, we may be required to make payments of up to $57 million to Con Edison Gas Pipeline and Storage Northeast, LLC after December 31, 2020 if certain criteria are not met by Stagecoach Gas by December 31, 2020, including achieving certain performance targets on growth capital projects. These growth capital projects depend on the construction of third-party expansion projects, and those third-party projects experienced regulatory and other delays that caused Stagecoach Gas to delay its growth capital projects. As a result, our consolidated balance sheet at June 30, 2020 reflects a $19 million current liability included in accrued expenses and other liabilities and a $38 million other long-term liability related to the anticipated settlement of this obligation.

Guarantee. CEQP issued a guarantee under which CEQP would be required to pay up to $10 million if Crestwood Permian fails to honor its obligations to Crestwood Permian Basin LLC, a 50% equity investment of Crestwood Permian, in the event Crestwood Permian Basin LLC fails to satisfy its obligations under its gas gathering agreement. We do not believe that it is probable that this guarantee will result in future losses based on our assessment of the nature of the guarantee, the financial condition of the guaranteed party and the period of time that the guarantee has been outstanding, and as a result, we have not recorded a liability on our consolidated balance sheets at June 30, 2020 and December 31, 2019.

XML

Risk Management

6 Months Ended

Jun. 30, 2020

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

Risk Management

Risk Management

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

Commodity Derivative Instruments and Price Risk Management

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 costs of product sold in our consolidated statements of operations. The following table summarizes the impact to our consolidated statements of operations related to our commodity-based derivatives reflected in operating revenues and costs of product/services sold during the three and six months ended June 30, 2020 and 2019 (in millions):

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2020		2019		2020		2019
Product revenues	$	18.0	$	40.2	$	93.0	$	144.3
Gain reflected in costs of product/services sold	$	6.8	$	9.9	$	28.8	$	7.0

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 costs of product/services sold related to these instruments.

Commodity Price and Credit Risk

Notional Amounts and Terms

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

	June 30, 2020		December 31, 2019
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, ethane, butane, heating oil and crude oil (MMBbls)	64.4	69.8	33.5	36.6
Natural gas (Bcf)	10.2	17.5	3.7	8.7

Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly, notional amounts do not reflect our monetary exposure to market or credit risks. All contracts subject to price risk had a maturity of 37 months or less; however, 83% 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. For example, in June 2020, Chesapeake Energy Corporation (Chesapeake), our major customer in the Powder River Basin, filed for protection under Chapter 11 of the U.S. Bankruptcy Code and in July 2020, Bruin E&P Partners, LLC (Bruin), our major customer in the Bakken also filed for protection under Chapter 11 of the U.S. Bankruptcy Code.  Chesapeake and Bruin were current on all amounts due to us as of June 30, 2020 and we obtained letters of credit from Chesapeake to provide additional cash flow protection related to their credit risk. 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 New York Mercantile Exchange (NYMEX) broker related to our net asset or liability position with such broker. All collateral amounts have been netted against the asset or liability with the respective counterparty and are reflected in our consolidated balance sheets as assets and liabilities from price risk management activities.

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

	June 30, 2020		December 31, 2019
Aggregate fair value of derivative instruments with credit-risk-related contingent features(1)	$	20.3	$	1.6
NYMEX-related net derivative asset (liability) position	$	1.9	$	(28.8	)
NYMEX-related cash collateral posted	$	26.8	$	40.4
Cash collateral received, net	$	21.1	$	16.9

(1)

At June 30, 2020 and December 31, 2019, we posted less than $0.1 million of collateral associated with these derivatives.

XML

Fair Value Measurements

6 Months Ended

Jun. 30, 2020

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

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

• Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of financial instruments such as exchange-traded derivatives, listed equities and US government treasury securities.

• Level 2—Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives such as over the counter (OTC) forwards, options and physical exchanges.

• Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

Cash, Accounts Receivable and Accounts Payable

As of June 30, 2020 and December 31, 2019, the carrying amounts of cash, accounts receivable and accounts payable approximate fair value based on the short-term nature of these instruments.

Credit Facility

The fair value of the amounts outstanding under our Crestwood Midstream credit facility approximates the carrying amounts as of June 30, 2020 and December 31, 2019, due primarily to the variable nature of the interest rate of the instrument, which is considered a Level 2 fair value measurement.

Senior Notes

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

	June 30, 2020				December 31, 2019
	Carrying  Amount		Fair Value		Carrying  Amount		Fair Value
2023 Senior Notes	$	695.9	$	623.0	$	695.1	$	714.0
2025 Senior Notes	$	495.0	$	435.0	$	494.4	$	514.4
2027 Senior Notes	$	592.6	$	499.2	$	592.1	$	610.1

Financial Assets and Liabilities

As of June 30, 2020 and December 31, 2019, 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 heating oil, crude oil, NGLs and natural gas. Our derivative instruments consist of forwards, swaps, futures, physical exchanges and options.

Our derivative instruments that are traded on the NYMEX have been categorized as Level 1.

Our derivative instruments also include OTC contracts, which are not traded on a public exchange. The fair values of these derivative instruments are determined based on inputs that are readily available in public markets or can be derived from information available in publicly quoted markets. These instruments have been categorized as Level 2.

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

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

The following tables set forth by level within the fair value hierarchy, our financial instruments that were accounted for at fair value on a recurring basis at June 30, 2020 and December 31, 2019 (in millions):

	June 30, 2020
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting(1)			Collateral/Margin Received or Paid		Fair Value
Assets
Assets from price risk management	$	26.2	$	187.8	$	—	$	214.0	$	(186.3	)	$	16.7	$	44.4
Suburban Propane Partners, L.P. units(2)	2.0		—		—		2.0		—			—		2.0
Total assets at fair value	$	28.2	$	187.8	$	—	$	216.0	$	(186.3	)	$	16.7	$	46.4
Liabilities
Liabilities from price risk management	$	29.7	$	177.8	$	—	$	207.5	$	(186.3	)	$	11.0	$	32.2
Total liabilities at fair value	$	29.7	$	177.8	$	—	$	207.5	$	(186.3	)	$	11.0	$	32.2

	December 31, 2019
	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	$	3.7	$	164.0	$	—	$	167.7	$	(122.3	)	$	(2.2	)	$	43.2
Suburban Propane Partners, L.P. units(2)	3.1		—		—		3.1		—			—			3.1
Total assets at fair value	$	6.8	$	164.0	$	—	$	170.8	$	(122.3	)	$	(2.2	)	$	46.3
Liabilities
Liabilities from price risk management	$	2.8	$	151.9	$	—	$	154.7	$	(122.3	)	$	(25.7	)	$	6.7
Total liabilities at fair value	$	2.8	$	151.9	$	—	$	154.7	$	(122.3	)	$	(25.7	)	$	6.7

(1) Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions.

(2)

Amount is reflected in other assets on CEQP’s consolidated balance sheets.

XML

Long-Term Debt

6 Months Ended

Jun. 30, 2020

Text Block [Abstract]

Long-Term Debt

Long-Term Debt

Long-term debt consisted of the following at June 30, 2020 and December 31, 2019 (in millions):

	June 30, 2020		December 31, 2019
Credit Facility	$	801.2	$	557.0
2023 Senior Notes	700.0		700.0
2025 Senior Notes	500.0		500.0
2027 Senior Notes	600.0		600.0
Other	0.6		0.6
Less: deferred financing costs, net	25.9		29.1
Total debt	2,575.9		2,328.5
Less: current portion	0.2		0.2
Total long-term debt, less current portion	$	2,575.7	$	2,328.3

Credit Facility

At June 30, 2020, Crestwood Midstream had $424.9 million of available capacity under its credit facility considering the most restrictive debt covenants in its credit agreement. At June 30, 2020 and December 31, 2019, Crestwood Midstream’s outstanding standby letters of credit were $23.9 million and $31.7 million. Borrowings under the credit facility accrue interest at prime or Eurodollar based rates plus applicable spreads, which resulted in interest rates between 2.43% and 4.50% at June 30, 2020 and 3.96% and 6.00% at December 31, 2019. The weighted-average interest rate on outstanding borrowings as of June 30, 2020 and December 31, 2019 was 2.44% and 4.00%.

Crestwood Midstream is required under its credit agreement to maintain a net debt to consolidated EBITDA ratio (as defined in its credit agreement) of not more than 5.50 to 1.0, a consolidated EBITDA to consolidated interest expense ratio (as defined in its credit agreement) of not less than 2.50 to 1.0, and a senior secured leverage ratio (as defined in its credit agreement) of not more than 3.75 to 1.0. At June 30, 2020, the net debt to consolidated EBITDA ratio was approximately 4.16 to 1.0, the consolidated EBITDA to consolidated interest expense ratio was approximately 4.62 to 1.0, and the senior secured leverage ratio was 1.28 to 1.0.

Senior Notes

In April 2019, Crestwood Midstream issued $600 million of 5.625% unsecured senior notes due 2027 (the 2027 Senior Notes). The 2027 Senior Notes mature on May 1, 2027, and interest is payable semi-annually in arrears on May 1 and November 1 of each year, beginning on November 1, 2019. The net proceeds from this offering of approximately $591.1 million were used to

repay a portion of the outstanding borrowings under our credit facility, which included approximately $250 million which was used to fund the acquisition of the remaining 50% equity interest in Jackalope.

XML

Earnings Per Limited Partner Unit

6 Months Ended

Jun. 30, 2020

Earnings Per Share [Abstract]

Earnings Per Limited Partner Unit

Earnings Per Limited Partner Unit

Our net income (loss) attributable to Crestwood Equity Partners is allocated to the subordinated and limited partner unitholders based on their ownership percentage after giving effect to net income attributable to the preferred units. We calculate basic net income per limited partner unit using the two-class method. Diluted net income per limited partner unit is computed using the treasury stock method, which considers the impact to net income 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 on net income attributable to Crestwood Equity Partners per limited partner unit 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, 2020 and 2019 (in millions):

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Preferred units (1)	7.1	—	7.1	7.1
Crestwood Niobrara’s preferred units(1)	8.2	—	8.2	—
Unit-based compensation performance units(1)	0.2	—	0.3	—
Subordinated units(1)	0.4	—	0.4	—

(1) For additional information regarding the potential conversion/redemption of our preferred units and Crestwood Niobrara’s preferred units to CEQP common units, and of our performance units and subordinated units, see our 2019 Annual Report on Form 10-K.

The table below shows CEQP’s net income per limited partner unit based on the number of basic and diluted limited partner units outstanding for the three and six months ended June 30, 2020 and 2019 (in millions, except for per unit data):

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2020			2019		2020			2019
Common unitholders’ interest in net income (loss)	$	(49.5	)	$	198.2	$	(97.8	)	$	193.3
Dilutive effect of net income attributable to preferred units	—			15.0		—			—
Dilutive effect of net income attributable to subordinated units	—			1.2		—			1.2
Diluted net income (loss)	$	(49.5	)	$	214.4	$	(97.8	)	$	194.5
Weighted-average limited partners’ units outstanding - basic	73.2			71.8		73.0			71.8
Dilutive effect of preferred units	—			7.1		—			—
Dilutive effect of Crestwood Niobrara preferred units	—			3.4		—			4.5
Dilutive effect of stock-based compensation performance units	—			0.3		—			0.3
Dilutive effect of subordinated units	—			0.4		—			0.4
Weighted-average limited partners’ units outstanding - diluted	73.2			83.0		73.0			77.0
Basic earnings per unit:
Net income (loss) per limited partner unit	$	(0.68	)	$	2.76	$	(1.34	)	$	2.69
Diluted earnings per unit:
Net income (loss) per limited partner unit	$	(0.68	)	$	2.58	$	(1.34	)	$	2.53

XML

Partners' Capital

6 Months Ended

Jun. 30, 2020

Statement of Partners' Capital [Abstract]

Partners' Capital

Partners’ Capital

Common Units

Effective April 1, 2020, we suspended the equity distribution program with certain financial institutions under which we were allowed to offer and sell, from time to time through one or more of these financial institutions, common units having an aggregate offering price of up to $250 million. We did not issue any common units under this program during the six months ended June 30, 2020 and 2019.

Distributions

Crestwood Equity

Limited Partners. A summary of CEQP’s limited partner quarterly cash distributions for the six months ended June 30, 2020 and 2019 is presented below:

Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2020
February 7, 2020	February 14, 2020	$	0.625	$	45.3
May 8, 2020	May 15, 2020	0.625		45.7
				$	91.0
2019
February 7, 2019	February 14, 2019	$	0.60	$	43.1
May 8, 2019	May 15, 2019	0.60		43.1
				$	86.2

On July 16, 2020, we declared a distribution of $0.625 per limited partner unit to be paid on August 14, 2020 to unitholders of record on August 7, 2020 with respect to the quarter ended June 30, 2020.

Preferred Unitholders. During the six months ended June 30, 2020 and 2019, we made cash distributions to our preferred unitholders of approximately $30.0 million in both periods. On July 16, 2020, the board of directors of our general partner authorized a cash distribution to our preferred unitholders of approximately $15.0 million for the quarter ended June 30, 2020.

Crestwood Midstream

During the six months ended June 30, 2020 and 2019, Crestwood Midstream paid cash distributions of $119.0 million and $117.5 million to Crestwood Equity.

Non-Controlling Partner

Crestwood Niobrara issued preferred interests to Jackalope Holdings, which are reflected as non-controlling interest in subsidiary apart from partners’ capital (i.e., temporary equity) on our consolidated balance sheets. In April 2019, Crestwood Niobrara issued $235 million in new preferred interests (Series A-3 Preferred Units) to Jackalope Holdings in conjunction with Crestwood Niobrara’s acquisition of the remaining 50% equity interest in Jackalope from Williams, at which time we began classifying our non-controlling interest in subsidiary apart from partners’ capital. We adjust the carrying amount of our non-controlling interest to its redemption value each period through net income attributable to non-controlling partner.

The following table shows the change in our non-controlling interest in subsidiary at June 30, 2020 and 2019 (in millions):

Balance at December 31, 2019	$	426.2
Contributions from non-controlling partner	2.8
Distributions to non-controlling partner	(18.5		)
Net income attributable to non-controlling partner	20.1
Balance at June 30, 2020	$	430.6

Balance at December 31, 2018	$	—
Reclassification of Series A-2 Preferred Units	178.8
Issuance of Series A-3 Preferred Units	235.0
Net income attributable to non-controlling partner	10.6
Balance at June 30, 2019	$	424.4

Crestwood Niobrara makes quarterly cash distributions on its preferred interests within 30 days after the end of each quarter. During the six months ended June 30, 2020 and 2019, Crestwood Niobrara paid cash distributions of $18.5 million and $6.6 million to Jackalope Holdings. In July 2020, Crestwood Niobrara paid cash distributions to Jackalope Holdings of approximately$9.3 million for the quarter ended June 30, 2020. During the six months ended June 30, 2020, we received contributions of $2.8 million from our non-controlling partner to fund our Jackalope expansion projects.

Other

In February 2020, Crestwood Equity issued 184,528 performance units under the Crestwood Equity Partners LP Long Term Incentive Plan (Crestwood LTIP). The performance units are designed to provide an incentive for continuous employment to certain key employees. The vesting of performance units is subject to the attainment of certain performance and market goals over a three-year period, and entitle a participant to receive common units of Crestwood Equity without payment of an exercise price upon vesting. As of June 30, 2020, we had total unamortized compensation expense of approximately $3.7 million related to these performance units, which we expect will be amortized during the next three years. During the three and six months ended June 30, 2020, we recognized compensation expense of approximately $0.6 million and $0.8 million related to these performance units, which is included in general and administrative expenses on our consolidated statements of operations.

During the six months ended June 30, 2020, 405,620 performance units that were previously issued under the Crestwood LTIP vested, and as a result of the attainment of certain performance and market goals and related distributions during the three years that the awards were outstanding, we issued 838,556 common units during the six months ended June 30, 2020 related to those performance units.

XML

Commitments and Contingencies

6 Months Ended

Jun. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Legal Proceedings

Linde Lawsuit. On December 23, 2019, Linde Engineering North America Inc. (Linde) filed a lawsuit in the District Court of Harris County, Texas alleging that Arrow Field Services, LLC, our consolidated subsidiary, and Crestwood Midstream breached a contract entered into in March 2018 under which Linde was to provide engineering, procurement and construction services to us related to the completion of the construction of the Bear Den II cryogenic processing plant. Linde claims damages of $55 million in unpaid invoices and other damages. This matter is not an insurable event based on our insurance policies, and we are unable to predict the outcome for this matter.

General. We are periodically involved in litigation proceedings. If we determine that a negative outcome is probable and the amount of loss is reasonably estimable, then we accrue the estimated amount. The results of litigation proceedings cannot be predicted with certainty. We could incur judgments, enter into settlements or revise our expectations regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations or cash flows in the period in which the amounts are paid and/or accrued. As of June 30, 2020 and December 31, 2019, we had approximately $10.9 million and $10.7 million accrued for outstanding legal matters. Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures for which we can estimate will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures.

Any loss estimates are inherently subjective, based on currently available information, and are subject to management’s judgment and various assumptions. Due to the inherently subjective nature of these estimates and the uncertainty and unpredictability surrounding the outcome of legal proceedings, actual results may differ materially from any amounts that have been accrued.

Regulatory Compliance

In the ordinary course of our business, we are subject to various laws and regulations. In the opinion of our management, compliance with current laws and regulations will not have a material effect on our results of operations, cash flows or financial condition.

Environmental Compliance

Our operations are subject to stringent and complex laws and regulations pertaining to worker health, safety, and the environment. We are subject to laws and regulations at the federal, state, regional and local levels that relate to air and water quality, hazardous and solid waste management and disposal, and other environmental matters. The cost of planning, designing, constructing and operating our facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures.

During 2014, we experienced three releases totaling approximately 28,000 barrels of produced water on our Arrow water gathering system located on the Fort Berthold Indian Reservation in North Dakota. We immediately notified the National Response Center, the Three Affiliated Tribes and numerous other regulatory authorities. Thereafter, we contained and cleaned up the releases, and placed the impacted segments of these water lines back into service. In May 2015, we experienced a release of approximately 5,200 barrels of produced water on our Arrow water gathering system, immediately notified numerous regulatory authorities and other third parties, and thereafter contained and cleaned up the releases.

In August 2015, we received a notice of violation from the Three Affiliated Tribes’ Environmental Division related to our 2014 produced water releases on the Fort Berthold Indian Reservation. The notice of violation imposes fines and requests reimbursements exceeding $1.1 million; however, the notice of violation was stayed on September 15, 2015. Our discussions regarding the notice of violation continue with the Three Affiliated Tribes.

During September 2019, we experienced two produced water releases totaling approximately 5,000 barrels on our Arrow system located on the Fort Berthold Indian Reservation in North Dakota.  We immediately notified the National Response Center, the State of North Dakota, the Three Affiliated Tribes, affected landowners and numerous other regulatory authorities. We are substantially complete with the remediation efforts and continue to monitor the impact of both spills.

In response to the water releases on our Arrow system, we removed approximately 30 miles of water gathering pipeline from service. In addition, we are currently in the process of replacing certain sections of our water gathering pipeline with pipeline composed of higher capacity material that is more suitable to the environment and climate conditions in the Bakken, which will increase water gathering capacity on the Arrow system and further our commitment to sustainability and environmental stewardship in the areas where we live and operate.

We will continue our remediation efforts to ensure the impacted lands are restored to their prior state. We believe these releases are insurable events under our policies, and we have notified our carriers of these events. We have not recorded an insurance receivable as of June 30, 2020.

At June 30, 2020 and December 31, 2019, our accrual of approximately $3.8 million and $6.7 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 $3.8 million to $8.0 million at June 30, 2020.

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 disposed retail propane operations, provided they were reported prior to August 1, 2012. The following table summarizes CEQP’s and CMLP’s self-insurance reserves at June 30, 2020 and December 31, 2019 (in millions):

	CEQP				CMLP
	June 30, 2020		December 31, 2019		June 30, 2020		December 31, 2019
Self-insurance reserves(1)	$	9.4	$	9.7	$	8.3	$	8.3

(1) At June 30, 2020, CEQP and CMLP classified approximately $6.2 million and $5.2 million, respectively of these reserves as other long-term liabilities on their consolidated balance sheets.

Leases

The following table summarizes the balance sheet information related to our operating and finance leases at June 30, 2020 and December 31, 2019 (in millions):

	June 30,		December 31,
	2020		2019
Operating Leases
Operating lease right-of-use assets, net	$	44.2	$	53.8
Accrued expenses and other liabilities	$	17.8	$	18.1
Long-term operating lease liabilities	32.9		41.5
Total operating lease liabilities	$	50.7	$	59.6
Finance Leases
Property, plant and equipment	$	14.9	$	14.9
Less: accumulated depreciation	7.2		5.4
Property, plant and equipment, net	$	7.7	$	9.5
Accrued expenses and other liabilities	$	3.3	$	3.2
Other long-term liabilities	3.6		5.2
Total finance lease liabilities	$	6.9	$	8.4

Lease expense. Our operating lease expense, net totaled $7.1 million and $7.3 million for the three months ended June 30, 2020 and 2019 and $14.6 million for both the six months ended June 30, 2020 and 2019. Our finance lease expense totaled $1.1 million for both the three months ended June 30, 2020 and 2019 and $2.2 million for both the six months ended June 30, 2020 and 2019.

Guarantees and Indemnifications

We are involved in various joint ventures that sometimes require financial and performance guarantees. In a financial guarantee, we are obligated to make payments if the guaranteed party fails to make payments under, or violates the terms of, the financial arrangement. In a performance guarantee, we provide assurance that the guaranteed party will execute on the terms of the contract. If they do not, we are required to perform on their behalf. We also periodically provide indemnification arrangements related to assets or businesses we have sold. For a further description of our guarantees associated with our joint ventures, see Note 5.

Our potential exposure under guarantee and indemnification arrangements can range from a specified amount to an unlimited dollar amount, depending on the nature of the claim, specificity as to duration, and the particular transaction. As of June 30, 2020 and December 31, 2019, we have no amounts accrued for these guarantees.

XML

Related Party Transactions

6 Months Ended

Jun. 30, 2020

Related Party Transactions [Abstract]

Related Party Transactions

Related Party Transactions

Crestwood Holdings LLC (Crestwood Holdings) indirectly owns both CEQP’s and CMLP’s general partner. The affiliates of Crestwood Holdings and its owners are considered CEQP’s and CMLP’s related parties. We enter into transactions with our affiliates within the ordinary course of business, including gas gathering and processing services, product purchases, marketing

services and various operating agreements. We also enter into transactions with our affiliates related to services provided on our expansion projects. During the six months ended June 30, 2020 and 2019, we paid approximately $2.9 million and $5.1 million of capital expenditures to Applied Consultants, Inc., an affiliate of Crestwood Holdings.

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 2019 Annual Report on Form 10-K.

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2020			2019			2020		2019
Revenues at CEQP and CMLP(1)	$	7.5		$	1.3		$	15.0	$	2.5
Costs of product/services sold at CEQP and CMLP(2)	$	3.6		$	0.9		$	6.8	$	35.3
Operations and maintenance expenses charged by CEQP and CMLP(3)	$	5.5		$	5.9		$	11.7	$	13.4
General and administrative expenses charged by CEQP to CMLP, net(4)	$	10.9		$	10.1		$	18.0	$	21.1
General and administrative expenses at CEQP charged to (from) Crestwood Holdings, net(5)	$	(1.5	)	$	(0.1	)	$	11.3	$	(5.3	)

(1) Includes $7.5 million and $15.0 million during the three and six months ended June 30, 2020 related to the sale of NGLs to a subsidiary of Crestwood Permian and $1.3 million and $2.5 million during the three and six months ended June 30, 2019 related to the sale of natural gas to a subsidiary of Stagecoach Gas.

(2) Includes (i) $3.2 million and $6.4 million during the three and six months ended June 30, 2020 and $0.9 million and $9.1 million during the three and six months ended June 30, 2019 related to purchases of NGLs from a subsidiary of Crestwood Permian; (ii) $0.1 million during both the three and six months ended June 30, 2020 related to purchases from a subsidiary of Tres Palacios Holdings, (iii) less than $0.1 million and $2.3 million during the three and six months ended June 30, 2019 related to purchases of natural gas from a subsidiary of Stagecoach Gas; and (iv) $0.3 million during both the three and six months ended June 30, 2020 and less than $0.1 million and $23.9 million during the three and six months ended June 30, 2019 related to an agency marketing agreement with Ascent Resources - Utica, LLC, an affiliate of Crestwood Holdings.

(3) We have operating agreements with certain of our unconsolidated affiliates pursuant to which we charge them operations and maintenance expenses in accordance with their respective agreements, and these charges are reflected as a reduction of operations and maintenance expenses in our consolidated statements of operations. During the three and six months ended June 30, 2020, we charged $1.6 million and $3.3 million to Stagecoach Gas, $1.1 million and $2.2 million to Tres Palacios, and $2.8 million and $6.2 million to Crestwood Permian under these agreements. During the three and six months ended June 30, 2019, we charged $1.9 million and $3.9 million to Stagecoach Gas, $1.0 million and $2.2 million to Tres Palacios, and $3.0 million and $6.8 million to Crestwood Permian. During the six months ended June 30, 2019, we charged $0.5 million to Jackalope under an operating agreement prior to our acquisition of the remaining 50% equity interest in Jackalope in Williams.

(4) Includes $11.9 million and $20.1 million of unit-based compensation charges allocated from CEQP to CMLP for the three and six months ended June 30, 2020 and $11.0 million and $22.9 million for the three and six months ended June 30, 2019. In addition, includes $1.0 million and $2.1 million of CMLP’s general and administrative costs allocated to CEQP during the three and six months ended June 30, 2020 and $0.9 million and $1.8 million during the three and six months ended June 30, 2019.

(5) Includes $1.7 million of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the three months ended June 30, 2020, a $10.9 million reduction of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the six months ended June 30, 2020 and $0.2 million and $5.6 million of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the three and six months ended June 30, 2019. In addition, includes $0.2 million and $0.4 million of CEQP’s general and administrative costs allocated to Crestwood Holdings during the three and six months ended June 30, 2020 and $0.1 million and $0.3 million during the three and six months ended June 30, 2019.

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

	June 30, 2020		December 31, 2019
Accounts receivable at CEQP and CMLP	$	10.9	$	7.3
Accounts payable at CEQP	$	6.9	$	15.6
Accounts payable at CMLP	$	4.5	$	13.1

XML

Segments

6 Months Ended

Jun. 30, 2020

Segment Reporting [Abstract]

Segments

Segments

Financial Information

We have three operating and reportable segments: (i) gathering and processing operations; (ii) storage and transportation operations; and (iii) marketing, supply and logistics operations. Our corporate operations include all general and administrative expenses that are not allocated to our reportable segments. We assess the performance of our operating segments based on EBITDA, which is defined as income before income taxes, plus interest and debt expense, net and depreciation, amortization and accretion expense.

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

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2020			2019		2020			2019
Net income (loss)	$	(24.3	)	$	225.0	$	(47.7	)	$	239.1
Add:
Interest and debt expense, net	34.0			27.8		66.6			52.7
Provision (benefit) for income taxes	(0.1		)	0.3		(0.1		)	0.3
Depreciation, amortization and accretion	61.0			49.3		117.1			89.1
EBITDA	$	70.6		$	302.4	$	135.9		$	381.2

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

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2020			2019		2020			2019
Net income (loss)	$	(26.8	)	$	222.9	$	(52.4	)	$	234.5
Add:
Interest and debt expense, net	34.0			27.8		66.6			52.7
Provision (benefit) for income taxes	(0.2		)	0.3		(0.2		)	0.3
Depreciation, amortization and accretion	64.6			52.7		124.2			96.1
EBITDA	$	71.6		$	303.7	$	138.2		$	383.6

The following tables summarize CEQP’s and CMLP’s reportable segment data for the three and six months ended June 30, 2020 and 2019 (in millions). Intersegment revenues included in the following tables are accounted for as arms-length transactions that apply our revenue recognition policies as described in our 2019 Annual Report on Form 10-K. Included in earnings from unconsolidated affiliates, net below was approximately $9.5 million and $10.3 million of our proportionate share of interest expense, depreciation and amortization expense and gains (losses) on long-lived assets, net recorded by our equity investments for the three months ended June 30, 2020 and 2019 and $23.3 million and $23.0 million for the six months ended June 30, 2020 and 2019.

Crestwood Equity

	Three Months Ended June 30, 2020
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	114.5		$	3.1	$	235.1		$	—		$	352.7
Intersegment revenues	14.3			2.4		(16.7		)	—			—
Costs of product/services sold	21.3			0.1		204.3			—			225.7
Operations and maintenance expense	19.3			0.7		11.6			—			31.6
General and administrative expense	—			—		—			29.5			29.5
Loss on long-lived assets, net	(3.6		)	—		(0.2		)	—			(3.8		)
Earnings (loss) from unconsolidated affiliates, net	(1.0		)	9.4		—			—			8.4
Other income, net	—			—		—			0.1			0.1
EBITDA	$	83.6		$	14.1	$	2.3		$	(29.4	)	$	70.6
Goodwill	$	45.9		$	—	$	92.7		$	—		$	138.6
Total assets	$	3,589.8		$	964.7	$	736.9		$	32.3		$	5,323.7

	Three Months Ended June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	199.7		$	4.9	$	478.8		$	—		$	683.4
Intersegment revenues	25.4			3.2		(28.6		)	—			—
Costs of product/services sold	108.9			—		428.3			—			537.2
Operations and maintenance expense	24.6			0.9		9.2			—			34.7
General and administrative expense	—			—		—			22.3			22.3
Gain (loss) on long-lived assets, net	(0.2		)	—		—			0.2			—
Gain on acquisition	209.4			—		—			—			209.4
Earnings (loss) from unconsolidated affiliates, net	(2.8		)	6.5		—			—			3.7
Other income, net	—			—		—			0.1			0.1
EBITDA	$	298.0		$	13.7	$	12.7		$	(22.0	)	$	302.4

	Six Months Ended June 30, 2020
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	329.4		$	6.6	$	744.6		$	—		$	1,080.6
Intersegment revenues	54.3			5.0		(59.3		)	—			—
Costs of product/services sold	129.6			0.3		630.2			—			760.1
Operations and maintenance expense	46.3			2.1		20.8			—			69.2
General and administrative expense	—			—		—			44.4			44.4
Loss on long-lived assets, net	(4.6		)	—		(0.2		)	—			(4.8		)
Goodwill impairment	(80.3		)	—		—			—			(80.3		)
Earnings (loss) from unconsolidated affiliates, net	(0.2		)	14.1		—			—			13.9
Other income, net	—			—		—			0.2			0.2
EBITDA	$	122.7		$	23.3	$	34.1		$	(44.2	)	$	135.9
Goodwill	$	45.9		$	—	$	92.7		$	—		$	138.6
Total assets	$	3,589.8		$	964.7	$	736.9		$	32.3		$	5,323.7

	Six Months Ended June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	382.0		$	12.7	$	1,123.9		$	—		$	1,518.6
Intersegment revenues	78.2			6.8		(85.0		)	—			—
Costs of product/services sold	246.9			—		985.9			—			1,232.8
Operations and maintenance expense	42.7			1.9		18.7			—			63.3
General and administrative expense	—			—		—			59.5			59.5
Gain (loss) on long-lived assets, net	(2.0		)	—		(0.2		)	0.2			(2.0		)
Gain on acquisition	209.4			—		—			—			209.4
Earnings (loss) from unconsolidated affiliates, net	(3.0		)	13.6		—			—			10.6
Other income, net	—			—		—			0.2			0.2
EBITDA	$	375.0		$	31.2	$	34.1		$	(59.1	)	$	381.2

Crestwood Midstream

	Three Months Ended June 30, 2020
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	114.5		$	3.1	$	235.1		$	—		$	352.7
Intersegment revenues	14.3			2.4		(16.7		)	—			—
Costs of product/services sold	21.3			0.1		204.3			—			225.7
Operations and maintenance expense	19.3			0.7		11.6			—			31.6
General and administrative expense	—			—		—			28.4			28.4
Loss on long-lived assets, net	(3.6		)	—		(0.2		)	—			(3.8		)
Earnings (loss) from unconsolidated affiliates, net	(1.0		)	9.4		—			—			8.4
EBITDA	$	83.6		$	14.1	$	2.3		$	(28.4	)	$	71.6
Goodwill	$	45.9		$	—	$	92.7		$	—		$	138.6
Total assets	$	3,742.1		$	964.7	$	736.9		$	28.6		$	5,472.3

	Three Months Ended June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	199.7		$	4.9	$	478.8		$	—		$	683.4
Intersegment revenues	25.4			3.2		(28.6		)	—			—
Costs of product/services sold	108.9			—		428.3			—			537.2
Operations and maintenance expense	24.6			0.9		9.2			—			34.7
General and administrative expense	—			—		—			20.9			20.9
Gain (loss) on long-lived assets, net	(0.2		)	—		—			0.2			—
Gain on acquisition	209.4			—		—			—			209.4
Earnings (loss) from unconsolidated affiliates, net	(2.8		)	6.5		—			—			3.7
EBITDA	$	298.0		$	13.7	$	12.7		$	(20.7	)	$	303.7

	Six Months Ended June 30, 2020
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	329.4		$	6.6	$	744.6		$	—		$	1,080.6
Intersegment revenues	54.3			5.0		(59.3		)	—			—
Costs of product/services sold	129.6			0.3		630.2			—			760.1
Operations and maintenance expense	46.3			2.1		20.8			—			69.2
General and administrative expense	—			—		—			41.9			41.9
Loss on long-lived assets, net	(4.6		)	—		(0.2		)	—			(4.8		)
Goodwill impairment	(80.3		)	—		—			—			(80.3		)
Earnings (loss) from unconsolidated affiliates, net	(0.2		)	14.1		—			—			13.9
EBITDA	$	122.7		$	23.3	$	34.1		$	(41.9	)	$	138.2
Goodwill	$	45.9		$	—	$	92.7		$	—		$	138.6
Total assets	$	3,742.1		$	964.7	$	736.9		$	28.6		$	5,472.3

	Six Months Ended June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	382.0		$	12.7	$	1,123.9		$	—		$	1,518.6
Intersegment revenues	78.2			6.8		(85.0		)	—			—
Costs of product/services sold	246.9			—		985.9			—			1,232.8
Operations and maintenance expense	42.7			1.9		18.7			—			63.3
General and administrative expense	—			—		—			56.9			56.9
Gain (loss) on long-lived assets, net	(2.0		)	—		(0.2		)	0.2			(2.0		)
Gain on acquisition	209.4			—		—			—			209.4
Earnings (loss) from unconsolidated affiliates, net	(3.0		)	13.6		—			—			10.6
EBITDA	$	375.0		$	31.2	$	34.1		$	(56.7	)	$	383.6

XML

Revenue Recognition

6 Months Ended

Jun. 30, 2020

Revenue Recognition [Abstract]

Revenue Recognition

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 totaled $158.3 million and $225.0 million at June 30, 2020 and December 31, 2019, 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 17 years.

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

	June 30, 2020		December 31, 2019
Contract assets (non-current)	$	1.2	$	1.2
Contract liabilities (current)(1)	$	10.2	$	8.8
Contract liabilities (non-current)(1)	$	159.6	$	144.7

(1) During the three and six months ended June 30, 2020, we recognized revenues of approximately $3.1 million and $6.9 million that were previously included in contract liabilities (current) at December 31, 2019. The remaining change in our contract liabilities during the three and six months ended June 30, 2020, 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, 2020 (in millions):

Remainder of 2020	$	52.3
2021	94.1
2022	63.2
2023	8.0
2024	3.3
Total	$	220.9

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, 2020 and 2019 (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.

	Three Months Ended June 30, 2020
	Gathering and Processing		Storage and Transportation		Marketing, Supply and Logistics		Intersegment Elimination			Total
Topic 606 revenues
Gathering
Natural gas	$	33.2	$	—	$	—	$	—		$	33.2
Crude oil	17.9		—		—		—			17.9
Water	18.3		—		—		—			18.3
Processing
Natural gas	7.1		—		—		—			7.1
Compression
Natural gas	5.7		—		—		—			5.7
Storage
Crude oil	0.4		1.1		—		(0.8		)	0.7
NGLs	—		—		3.6		—			3.6
Pipeline
Crude oil	—		1.3		—		(0.4		)	0.9
NGLs	—		—		0.2		—			0.2
Transportation
Crude oil	1.5		—		0.3		—			1.8
NGLs	—		—		2.6		—			2.6
Rail Loading
Crude oil	—		2.9		—		(1.2		)	1.7
Product Sales
Natural gas	6.9		—		15.5		(6.8		)	15.6
Crude oil	34.8		—		102.0		(7.1		)	129.7
NGLs	3.0		—		92.4		(0.3		)	95.1
Other	—		0.2		0.2		(0.1		)	0.3
Total Topic 606 revenues	128.8		5.5		216.8		(16.7		)	334.4
Non-Topic 606 revenues(1)	—		—		18.3		—			18.3
Total revenues	$	128.8	$	5.5	$	235.1	$	(16.7	)	$	352.7

(1) Represents revenues primarily related to our commodity-based derivatives. See Note 6 for additional information related to our price risk management activities.

	Three Months Ended June 30, 2019
	Gathering and Processing		Storage and Transportation		Marketing, Supply and Logistics		Intersegment Elimination			Total
Topic 606 revenues
Gathering
Natural gas	$	42.9	$	—	$	—	$	—		$	42.9
Crude oil	15.1		—		—		—			15.1
Water	19.0		—		—		—			19.0
Processing
Natural gas	8.1		—		—		—			8.1
Compression
Natural gas	6.2		—		—		—			6.2
Storage
Crude oil	0.5		1.5		—		(0.5		)	1.5
NGLs	—		—		1.3		—			1.3
Pipeline
Crude oil	—		1.5		—		(0.5		)	1.0
Transportation
Crude oil	1.8		—		1.5		—			3.3
NGLs	—		—		2.1		—			2.1
Rail Loading
Crude oil	—		3.9		—		(1.4		)	2.5
Product Sales
Natural gas	10.9		—		7.9		(4.8		)	14.0
Crude oil	110.2		—		291.4		(16.0		)	385.6
NGLs	10.4		—		133.9		(4.5		)	139.8
Other	—		1.2		0.3		(0.9		)	0.6
Total Topic 606 revenues	225.1		8.1		438.4		(28.6		)	643.0
Non-Topic 606 revenues(1)	—		—		40.4		—			40.4
Total revenues	$	225.1	$	8.1	$	478.8	$	(28.6	)	$	683.4

(1) Represents revenues primarily related to our commodity-based derivatives. See Note 6 for additional information related to our price risk management activities.

	Six Months Ended June 30, 2020
	Gathering and Processing		Storage and Transportation		Marketing, Supply and Logistics		Intersegment Elimination			Total
Topic 606 revenues
Gathering
Natural gas	$	77.0	$	—	$	—	$	—		$	77.0
Crude oil	44.4		—		—		—			44.4
Water	41.3		—		—		—			41.3
Processing
Natural gas	17.3		—		—		—			17.3
Compression
Natural gas	12.0		—		—		—			12.0
Storage
Crude oil	0.9		1.7		—		(1.2		)	1.4
NGLs	—		—		5.2		—			5.2
Pipeline
Crude oil	—		2.9		—		(0.9		)	2.0
NGLs	—		—		0.2		—			0.2
Transportation
Crude oil	3.5		—		1.9		—			5.4
NGLs	—		—		4.3		—			4.3
Rail Loading
Crude oil	—		6.3		—		(2.6		)	3.7
Product Sales
Natural gas	18.9		—		33.8		(18.5		)	34.2
Crude oil	155.9		—		352.2		(23.4		)	484.7
NGLs	12.5		—		252.7		(12.2		)	253.0
Other	—		0.7		0.7		(0.5		)	0.9
Total Topic 606 revenues	383.7		11.6		651.0		(59.3		)	987.0
Non-Topic 606 revenues(1)	—		—		93.6		—			93.6
Total revenues	$	383.7	$	11.6	$	744.6	$	(59.3	)	$	1,080.6

(1) Represents revenues primarily related to our commodity-based derivatives. See Note 6 for additional information related to our price risk management activities.

	Six Months Ended June 30, 2019
	Gathering and Processing		Storage and Transportation		Marketing, Supply and Logistics		Intersegment Elimination			Total
Topic 606 revenues
Gathering
Natural gas	$	73.1	$	—	$	—	$	—		$	73.1
Crude oil	30.4		—		—		—			30.4
Water	35.8		—		—		—			35.8
Processing
Natural gas	10.6		—		—		—			10.6
Compression
Natural gas	12.2		—		—		—			12.2
Storage
Crude oil	1.0		2.9		—		(1.2		)	2.7
NGLs	—		—		2.6		—			2.6
Pipeline
Crude oil	—		3.2		—		(1.2		)	2.0
Transportation
Crude oil	3.3		—		3.0		—			6.3
NGLs	—		—		6.2		—			6.2
Rail Loading
Crude oil	—		11.1		—		(2.8		)	8.3
Product Sales
Natural gas	29.7		—		30.2		(11.4		)	48.5
Crude oil	241.8		—		581.5		(59.3		)	764.0
NGLs	22.3		—		355.4		(7.3		)	370.4
Other	—		2.3		0.3		(1.8		)	0.8
Total Topic 606 revenues	460.2		19.5		979.2		(85.0		)	1,373.9
Non-Topic 606 revenues(1)	—		—		144.7		—			144.7
Total revenues	$	460.2	$	19.5	$	1,123.9	$	(85.0	)	$	1,518.6

(1)

Represents revenues primarily related to our commodity-based derivatives. See Note 6 for additional information related to our price risk management activities.

XML

Condensed Consolidating Financial Information

6 Months Ended

Jun. 30, 2020

Condensed Financial Information Disclosure [Abstract]

Condensed Consolidating Financial Information

Condensed Consolidating Financial Information

Crestwood Midstream is a holding company (Parent) and owns no operating assets and has no significant operations independent of its subsidiaries. Obligations under Crestwood Midstream’s senior notes and its credit facility are jointly and severally guaranteed by substantially all of its subsidiaries, except for Crestwood Infrastructure, Crestwood Niobrara, Crestwood Pipeline and Storage Northeast LLC, PRBIC and Tres Holdings and their respective subsidiaries (collectively, Non-Guarantor Subsidiaries). Crestwood Midstream Finance Corp., the co-issuer of the senior notes, is Crestwood Midstream’s 100% owned subsidiary and has no material assets, operations, revenues or cash flows other than those related to its service as co-issuer of the Crestwood Midstream senior notes.

The tables below present condensed consolidating financial statements for Crestwood Midstream as Parent on a stand-alone, unconsolidated basis, and Crestwood Midstream’s combined guarantor and combined non-guarantor subsidiaries as of June 30, 2020 and December 31, 2019, and for the three and six months ended June 30, 2020 and 2019.  The financial information may not necessarily be indicative of the results of operations, cash flows or financial position had the subsidiaries operated as independent entities.

Crestwood Midstream Partners LP
Condensed Consolidating Balance Sheet
June 30, 2020
(in millions)
(unaudited)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	0.4	$	—	$	5.7	$	—		$	6.1
Accounts receivable	—		146.5		19.3		—			165.8
Inventory	—		88.9		—		—			88.9
Other current assets	—		52.8		0.3		—			53.1
Total current assets	0.4		288.2		25.3		—			313.9
Property, plant and equipment, net	—		2,410.1		783.6		—			3,193.7
Goodwill and intangible assets, net	—		671.2		284.5		—			955.7
Operating lease right-of-use assets, net	—		41.5		2.7		—			44.2
Investments in consolidated affiliates	4,501.0		—		—		(4,501.0		)	—
Investments in unconsolidated affiliates	—		—		961.9		—			961.9
Other non-current assets	—		2.4		0.5		—			2.9
Total assets	$	4,501.4	$	3,413.4	$	2,058.5	$	(4,501.0	)	$	5,472.3
Liabilities and capital
Current liabilities:
Accounts payable	$	—	$	114.6	$	1.5	$	—		$	116.1
Other current liabilities	25.2		114.8		24.8		—			164.8
Total current liabilities	25.2		229.4		26.3		—			280.9
Long-term liabilities:
Long-term debt, less current portion	2,575.7		—		—		—			2,575.7
Other long-term liabilities	—		165.8		118.2		—			284.0
Deferred income taxes	—		0.6		—		—			0.6
Total liabilities	2,600.9		395.8		144.5		—			3,141.2
Interest of non-controlling partner in subsidiary	—		—		430.6		—			430.6
Partners’ capital	1,900.5		3,017.6		1,483.4		(4,501.0		)	1,900.5
Total liabilities and capital	$	4,501.4	$	3,413.4	$	2,058.5	$	(4,501.0	)	$	5,472.3

Crestwood Midstream Partners LP
Condensed Consolidating Balance Sheet
December 31, 2019
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	1.8	$	—	$	23.6	$	—		$	25.4
Accounts receivable	—		229.1		12.8		—			241.9
Inventory	—		53.7		—		—			53.7
Other current assets	—		54.6		0.2		—			54.8
Total current assets	1.8		337.4		36.6		—			375.8
Property, plant and equipment, net	—		2,331.3		736.2		—			3,067.5
Goodwill and intangible assets, net	—		650.7		373.4		—			1,024.1
Operating lease right-of-use assets, net	—		51.0		2.8		—			53.8
Investments in consolidated affiliates	4,451.6		—		—		(4,451.6		)	—
Investments in unconsolidated affiliates	—		—		980.4		—			980.4
Other non-current assets	—		1.9		0.5		—			2.4
Total assets	$	4,453.4	$	3,372.3	$	2,129.9	$	(4,451.6	)	$	5,504.0
Liabilities and capital
Current liabilities:
Accounts payable	$	—	$	175.9	$	10.7	$	—		$	186.6
Other current liabilities	25.8		123.9		17.6		—			167.3
Total current liabilities	25.8		299.8		28.3		—			353.9
Long-term liabilities:
Long-term debt, less current portion	2,328.3		—		—		—			2,328.3
Other long-term liabilities	—		174.8		120.8		—			295.6
Deferred income taxes	—		0.7		—		—			0.7
Total liabilities	2,354.1		475.3		149.1		—			2,978.5
Interest of non-controlling partner in subsidiary	—		—		426.2		—			426.2
Partners’ capital	2,099.3		2,897.0		1,554.6		(4,451.6		)	2,099.3
Total liabilities and capital	$	4,453.4	$	3,372.3	$	2,129.9	$	(4,451.6	)	$	5,504.0

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Three Months Ended June 30, 2020
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	336.5		$	16.2		$	—		$	352.7
Costs of product/services sold	—			225.5			0.2			—			225.7
Operating expenses and other:
Operations and maintenance	—			26.5			5.1			—			31.6
General and administrative	14.8			13.6			—			—			28.4
Depreciation, amortization and accretion	—			50.3			14.3			—			64.6
Loss on long-lived assets, net	—			2.0			1.8			—			3.8
	14.8			92.4			21.2			—			128.4
Operating income (loss)	(14.8		)	18.6			(5.2		)	—			(1.4		)
Earnings from unconsolidated affiliates, net	—			—			8.4			—			8.4
Interest and debt expense, net	(33.9		)	(0.1		)	—			—			(34.0		)
Equity in net income (loss) of subsidiaries	11.7			—			—			(11.7		)	—
Income (loss) before income taxes	(37.0		)	18.5			3.2			(11.7		)	(27.0		)
Benefit for income taxes	—			0.2			—			—			0.2
Net income (loss)	(37.0		)	18.7			3.2			(11.7		)	(26.8		)
Net income attributable to non-controlling partner in subsidiary	—			—			10.2			—			10.2
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(37.0	)	$	18.7		$	(7.0	)	$	(11.7	)	$	(37.0	)

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Three Months Ended June 30, 2019
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	663.2		$	20.2		$	—		$	683.4
Costs of product/services sold	—			537.2			—			—			537.2
Operating expenses:
Operations and maintenance	—			27.5			7.2			—			34.7
General and administrative	9.7			11.2			—			—			20.9
Depreciation, amortization and accretion	—			43.0			9.7			—			52.7
Gain on acquisition	—			—			(209.4		)	—			(209.4		)
	9.7			81.7			(192.5		)	—			(101.1		)
Operating income (loss)	(9.7		)	44.3			212.7			—			247.3
Earnings from unconsolidated affiliates, net	—			—			3.7			—			3.7
Interest and debt expense, net	(28.0		)	0.2			—			—			(27.8		)
Equity in net income (loss) of subsidiaries	250.0			—			—			(250.0		)	—
Income (loss) before income taxes	212.3			44.5			216.4			(250.0		)	223.2
Provision for income taxes	—			(0.3		)	—			—			(0.3		)
Net income (loss)	212.3			44.2			216.4			(250.0		)	222.9
Net income attributable to non-controlling partner in subsidiary	—			—			10.6			—			10.6
Net income (loss) attributable to Crestwood Midstream Partners LP	$	212.3		$	44.2		$	205.8		$	(250.0	)	$	212.3

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Six Months Ended June 30, 2020
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	1,036.9		$	43.7		$	—		$	1,080.6
Costs of product/services sold	—			759.9			0.2			—			760.1
Operating expenses and other:
Operations and maintenance	—			58.3			10.9			—			69.2
General and administrative	32.7			9.2			—			—			41.9
Depreciation, amortization and accretion	—			98.1			26.1			—			124.2
Loss on long-lived assets, net	—			3.0			1.8			—			4.8
Goodwill impairment	—			—			80.3			—			80.3
	32.7			168.6			119.1			—			320.4
Operating income (loss)	(32.7		)	108.4			(75.6		)	—			0.1
Earnings from unconsolidated affiliates, net	—			—			13.9			—			13.9
Interest and debt expense, net	(66.3		)	(0.3		)	—			—			(66.6		)
Equity in net income (loss) of subsidiaries	26.5			—			—			(26.5		)	—
Income (loss) before income taxes	(72.5		)	108.1			(61.7		)	(26.5		)	(52.6		)
Benefit for income taxes	—			0.2			—			—			0.2
Net income (loss)	(72.5		)	108.3			(61.7		)	(26.5		)	(52.4		)
Net income attributable to non-controlling partner	—			—			20.1			—			20.1
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(72.5	)	$	108.3		$	(81.8	)	$	(26.5	)	$	(72.5	)

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Six Months Ended June 30, 2019
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	1,498.4		$	20.2		$	—		$	1,518.6
Costs of product/services sold	—			1,232.8			—			—			1,232.8
Operating expenses and other:
Operations and maintenance	—			56.1			7.2			—			63.3
General and administrative	28.4			28.5			—			—			56.9
Depreciation, amortization and accretion	—			86.4			9.7			—			96.1
Loss on long-lived assets, net	—			2.0			—			—			2.0
Gain on acquisition	—			—			(209.4		)	—			(209.4		)
	28.4			173.0			(192.5		)	—			8.9
Operating income (loss)	(28.4		)	92.6			212.7			—			276.9
Earnings from unconsolidated affiliates, net	—			—			10.6			—			10.6
Interest and debt expense, net	(52.7		)	—			—			—			(52.7		)
Equity in net income (loss) of subsidiaries	301.0			—			—			(301.0		)	—
Income (loss) before income taxes	219.9			92.6			223.3			(301.0		)	234.8
Provision for income taxes	—			(0.3		)	—			—			(0.3		)
Net income (loss)	219.9			92.3			223.3			(301.0		)	234.5
Net income attributable to non-controlling partner in subsidiary	—			—			14.6			—			14.6
Net income (loss) attributable to Crestwood Midstream Partners LP	$	219.9		$	92.3		$	208.7		$	(301.0	)	$	219.9

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2020
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities	$	(96.4	)	$	197.4		$	80.1		$	—		$	181.1
Cash flows from investing activities:
Acquisition, net of cash acquired	—			(162.3		)	—			—			(162.3		)
Purchases of property, plant and equipment	—			(56.2		)	(87.0		)	—			(143.2		)
Investment in unconsolidated affiliates	—			—			(6.0		)	—			(6.0		)
Capital distributions from unconsolidated affiliates	—			—			18.9			—			18.9
Capital distributions from consolidated affiliates	8.2			—			—			(8.2		)	—
Other	—			(0.3		)	—			—			(0.3		)
Net cash provided by (used in) investing activities	8.2			(218.8		)	(74.1		)	(8.2		)	(292.9		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	742.5			—			—			—			742.5
Payments on long-term debt	(498.2		)	—			—			—			(498.2		)
Payments on finance leases	—			(1.6		)	—			—			(1.6		)
Net proceeds from issuance of non-controlling interest	—			—			2.8			—			2.8
Distributions to partners	(119.0		)	—			(18.5		)	—			(137.5		)
Distributions to parent	—			—			(8.2		)	8.2			—
Taxes paid for unit-based compensation vesting	—			(15.5		)	—			—			(15.5		)
Change in intercompany balances	(38.5		)	38.5			—			—			—
Net cash provided by (used in) financing activities	86.8			21.4			(23.9		)	8.2			92.5
Net change in cash	(1.4		)	—			(17.9		)	—			(19.3		)
Cash at beginning of period	1.8			—			23.6			—			25.4
Cash at end of period	$	0.4		$	—		$	5.7		$	—		$	6.1

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2019
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities	$	(87.1	)	$	309.5		$	(27.3	)	$	—		$	195.1
Cash flows from investing activities:
Acquisition, net of cash acquired	—			—			(462.1		)	—			(462.1		)
Purchases of property, plant and equipment	—			(127.7		)	(77.0		)	—			(204.7		)
Investment in unconsolidated affiliates	—			—			(40.9		)	—			(40.9		)
Capital distributions from unconsolidated affiliates	—			—			24.2			—			24.2
Capital contributions to consolidated affiliates	(217.1		)	—			—			217.1			—
Other	—			(0.5		)	—			—			(0.5		)
Net cash provided by (used in) investing activities	(217.1		)	(128.2		)	(555.8		)	217.1			(684.0		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	1,544.0			—			—			—			1,544.0
Payments on long-term debt	(1,159.1		)	(0.4		)	—			—			(1,159.5		)
Payments on finance leases	—			(1.9		)	—			—			(1.9		)
Payments for debt-related deferred costs	(9.0		)	—			—			—			(9.0		)
Net proceeds from the issuance of non-controlling interest	—			—			235.0			—			235.0
Distributions to partners	(117.5		)	—			(6.6		)	—			(124.1		)
Contributions from parent	—			—			217.1			(217.1		)	—
Taxes paid for unit-based compensation vesting	—			(10.6		)	—			—			(10.6		)
Change in intercompany balances	30.7			(168.4		)	137.7			—			—
Net cash provided by (used in) financing activities	289.1			(181.3		)	583.2			(217.1		)	473.9
Net change in cash	(15.1		)	—			0.1			—			(15.0		)
Cash at beginning of period	16.5			—			—			—			16.5
Cash at end of period	$	1.4		$	—		$	0.1		$	—		$	1.5

XML

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

6 Months Ended

Jun. 30, 2020

Accounting Policies [Abstract]

Significant Accounting Policies

Significant Accounting Policies

There were no material changes in our significant accounting policies from those described in our 2019 Annual Report on Form 10-K. Below is an update of our accounting policies related to Goodwill and Accounts Receivable.

Goodwill

Our goodwill represents the excess of the amount we paid for a business over the fair value of the net identifiable assets acquired. We evaluate goodwill for impairment annually on December 31, and whenever events indicate that it is more likely than not that the fair value of a reporting unit could be less than its carrying amount. This evaluation requires us to compare the fair value of each of our reporting units to its carrying value (including goodwill). If the fair value exceeds the carrying amount, goodwill of the reporting unit is not considered impaired.

We estimate the fair value of our reporting units based on a number of factors, including discount rates, projected cash flows and the potential value we would receive if we sold the reporting unit. Estimating projected cash flows requires us to make

certain assumptions as it relates to the future operating performance of each of our reporting units (which includes assumptions, among others, about estimating future operating margins and related future growth in those margins, contracting efforts and the cost and timing of facility expansions) and assumptions related to our customers, such as their future capital and operating plans and their financial condition. When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. If the assumptions embodied in the projections prove inaccurate, we could incur a future impairment charge. In addition, the use of the income approach to determine the fair value of our reporting units (see further discussion of the use of the income approach below) could result in a different fair value if we had utilized a market approach, or a combination thereof.

The following table summarizes the goodwill of our various reporting units (in millions):

			Impairment during the six months ended
	December 31, 2019		June 30, 2020		June 30, 2020
Gathering and Processing
Arrow	$	45.9	$	—	$	45.9
Powder River Basin	80.3		80.3		—
Marketing, Supply and Logistics
NGL Marketing and Logistics	92.7		—		92.7
Total	$	218.9	$	80.3	$	138.6

During the first quarter of 2020, current and forward commodity prices significantly declined from their levels at December 31, 2019 due primarily to the decreases in energy demand as a result of the outbreak of the COVID-19 pandemic and actions taken by the Organization of the Petroleum Exporting Countries, Russia, the United States and other oil-producing countries relating to the oversupply of oil. We currently anticipate that the decrease in commodity prices will have a negative impact on certain of our customers in our gathering and processing segment, which could adversely impact the financial performance of certain of the reporting units within those operations.

Upon acquisition, we are required to record the assets, liabilities and goodwill of a reporting unit at its fair value on the date of acquisition. As a result, any level of decrease in the forecasted cash flows of these businesses or increases in the discount rates utilized to value those businesses from their respective acquisition dates would likely result in the fair value of the reporting unit falling below the carrying value of the reporting unit, and could result in an assessment of whether that reporting unit's goodwill is impaired.

We acquired our Powder River Basin reporting unit in 2019 and recorded it at fair value at that time. Based on the events that occurred during the first quarter of 2020 described above, we determined that the forecasted cash flows, and therefore the fair value, of our Powder River Basin reporting unit significantly decreased during the first quarter of 2020, and accordingly performed a quantitative impairment assessment of the goodwill related to that reporting unit during that period. Based on our quantitative assessment, which utilized the income approach, we determined that the goodwill associated with the Powder River Basin reporting unit should be fully impaired during the first quarter of 2020, and accordingly recorded an $80.3 million impairment of the goodwill attributed to that reporting unit during the first quarter of 2020. We did not record any impairments of the goodwill associated with our Arrow or NGL Marketing and Logistics reporting units during the six months ended June 30, 2020, as we do not have indicators that it is more likely than not that the fair value of those reporting units has declined to below their carrying value at June 30, 2020.

Accounts Receivable

Effective January 1, 2020, we adopted the provision of Accounting Standards Update 2016-13, Financial Instruments - Credit Losses (Topic 326), which provides revised guidance on evaluating accounts and notes receivable and other financial instruments for impairment. We record accounts receivable when products or services are delivered and it is probable that payment will be received for those products or services, and we do not record any interest or penalties on accounts receivable that are past due under the terms of the related arrangement or invoice until those amounts are received. Topic 326 requires companies to evaluate their financial instruments for impairment by recording an allowance for doubtful accounts and/or bad debt expense based on certain categories of instruments rather than a specific identification approach. We adopted the

provisions of this standard using a method to estimate the allowance for doubtful accounts that considered both the aging of our accounts receivable and the projected loss rate of our receivables. We write off accounts receivable, and the related allowance for doubtful accounts, when it becomes remote that payment for products or services will be received. On January 1, 2020, we recorded a $0.7 million increase to our allowance for doubtful accounts and a $0.7 million decrease to partners’ capital to reflect the cumulative effect of adopting the new standard. In addition, on January 1, 2020, Crestwood Permian Basin Holdings LLC (Crestwood Permian), our 50% equity investment, also adopted the provisions of Topic 326 and we recorded a decrease of approximately $0.2 million to our equity investment and a corresponding decrease to our partners’ capital to reflect our proportionate share of the cumulative effect of accounting change recorded by the equity investment related to the new standard. The adoption of this standard was not material to our other equity investments.

New Accounting Pronouncements Issued But Not Yet Adopted

Effective January 1, 2020, we adopted the provision of Accounting Standards Update 2016-13, Financial Instruments - Credit Losses (Topic 326), which provides revised guidance on evaluating accounts and notes receivable and other financial instruments for impairment. We record accounts receivable when products or services are delivered and it is probable that payment will be received for those products or services, and we do not record any interest or penalties on accounts receivable that are past due under the terms of the related arrangement or invoice until those amounts are received. Topic 326 requires companies to evaluate their financial instruments for impairment by recording an allowance for doubtful accounts and/or bad debt expense based on certain categories of instruments rather than a specific identification approach. We adopted the

provisions of this standard using a method to estimate the allowance for doubtful accounts that considered both the aging of our accounts receivable and the projected loss rate of our receivables. We write off accounts receivable, and the related allowance for doubtful accounts, when it becomes remote that payment for products or services will be received. On January 1, 2020, we recorded a $0.7 million increase to our allowance for doubtful accounts and a $0.7 million decrease to partners’ capital to reflect the cumulative effect of adopting the new standard. In addition, on January 1, 2020, Crestwood Permian Basin Holdings LLC (Crestwood Permian), our 50% equity investment, also adopted the provisions of Topic 326 and we recorded a decrease of approximately $0.2 million to our equity investment and a corresponding decrease to our partners’ capital to reflect our proportionate share of the cumulative effect of accounting change recorded by the equity investment related to the new standard. The adoption of this standard was not material to our other equity investments.

XML

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

6 Months Ended

Jun. 30, 2020

Accounting Policies [Abstract]

Schedule of Goodwill [Table Text Block]

The following table summarizes the goodwill of our various reporting units (in millions):

			Impairment during the six months ended
	December 31, 2019		June 30, 2020		June 30, 2020
Gathering and Processing
Arrow	$	45.9	$	—	$	45.9
Powder River Basin	80.3		80.3		—
Marketing, Supply and Logistics
NGL Marketing and Logistics	92.7		—		92.7
Total	$	218.9	$	80.3	$	138.6

XML

Certain Balance Sheet Information (Tables)

6 Months Ended

Jun. 30, 2020

Balance Sheet Related Disclosures [Abstract]

Schedule of Accrued Liabilities

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

	CEQP				CMLP
	June 30,		December 31,		June 30,		December 31,
	2020		2019		2020		2019
Accrued expenses	$	35.1	$	61.6	$	33.7	$	60.3
Accrued property taxes	8.2		6.1		8.2		6.1
Income tax payable	0.3		0.3		0.3		0.3
Interest payable	25.0		25.6		25.0		25.6
Accrued additions to property, plant and equipment	14.9		38.0		14.9		38.0
Contingent consideration	19.0		—		19.0		—
Operating leases	17.8		18.1		17.8		18.1
Finance leases	3.3		3.2		3.3		3.2
Deferred revenue	10.2		8.8		10.2		8.8
Total accrued expenses and other liabilities	$	133.8	$	161.7	$	132.4	$	160.4

Other Noncurrent Liabilities [Table Text Block]

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

	CEQP				CMLP
	June 30,		December 31,		June 30,		December 31,
	2020		2019		2020		2019
Contract liabilities	$	159.6	$	144.7	$	159.6	$	144.7
Contingent consideration	38.0		57.0		38.0		57.0
Operating leases	32.9		41.5		32.9		41.5
Asset retirement obligations	34.6		33.3		34.6		33.3
Other	20.6		25.1		18.9		19.1
Total other long-term liabilities	$	285.7	$	301.6	$	284.0	$	295.6

XML

Investments in Unconsolidated Affiliates (Tables)

6 Months Ended

Jun. 30, 2020

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments

Net Investments and Earnings

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

	Investment				Earnings (Loss) from Unconsolidated Affiliates						Earnings (Loss) from Unconsolidated Affiliates
	June 30,		December 31,		Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		2020			2019			2020			2019
Stagecoach Gas Services LLC(1)	$	802.8	$	814.4	$	9.2		$	6.4		$	18.4		$	13.4
Crestwood Permian Basin Holdings LLC(2)	114.7		121.8		(1.0		)	(3.3		)	(0.2		)	(6.7		)
Tres Palacios Holdings LLC(3)	40.6		35.9		0.1			0.1			0.1			0.3
Powder River Basin Industrial Complex, LLC(4)	3.8		8.3		0.1			—			(4.4		)	(0.1		)
Jackalope Gas Gathering Services, L.L.C.(5)	—		—		—			0.5			—			3.7
Total	$	961.9	$	980.4	$	8.4		$	3.7		$	13.9		$	10.6

(1) As of June 30, 2020, our equity in the underlying net assets of Stagecoach Gas Services LLC (Stagecoach Gas) exceeded our investment balance by approximately $51.3 million. This excess amount is entirely attributable to goodwill and, as such, is not subject to amortization. Our Stagecoach Gas investment is included in our storage and transportation segment.

(2) As of June 30, 2020, our equity in the underlying net assets of Crestwood Permian exceeded our investment balance by $9.7 million, and this excess amount is not subject to amortization. Our Crestwood Permian investment is included in our gathering and processing segment.

(3) As of June 30, 2020, our equity in the underlying net assets of Tres Palacios Holdings LLC (Tres Holdings) exceeded our investment balance by approximately $23.4 million. Our Tres Holdings investment is included in our storage and transportation segment.

(4) As of June 30, 2020, our equity in the underlying net assets of Powder River Basin Industrial Complex, LLC (PRBIC) approximates our investment balance. During the first quarter of 2020, we recorded our share of a long-lived asset impairment recorded by our PRBIC equity investment, which eliminated our $5.5 million historical basis difference between our investment balance and the equity in the underlying net assets of PRBIC, and also resulted in a $4.5 million reduction in our earnings from unconsolidated affiliates during the six months ended June 30, 2020. Our PRBIC investment is included in our storage and transportation segment.

(5) On April 9, 2019, Crestwood Niobrara acquired Williams 50% equity interest in Jackalope, and as a result, Crestwood Niobrara controls and owns 100% of the equity interests in Jackalope. As a result of this transaction, we eliminated our historical equity investment in Jackalope and began consolidating Jackalope’s operations. Our Jackalope investment was included in our gathering and processing segment.

Summarized Financial Information of Unconsolidated Affiliates

Below is the summarized operating results for our significant unconsolidated affiliates (in millions; amounts represent 100% of unconsolidated affiliate information):

	Six Months Ended June 30,
	2020							2019
	Operating Revenues		Operating Expenses		Net Income (Loss)			Operating Revenues		Operating Expenses		Net Income (Loss)
Stagecoach Gas	$	75.6	$	38.9	$	36.8		$	79.1	$	40.4	$	38.9
Other(1)	53.5		76.1		(21.6		)	55.4		62.2		(7.9		)
Total	$	129.1	$	115.0	$	15.2		$	134.5	$	102.6	$	31.0

(1) Includes our Crestwood Permian, Tres Holdings and PRBIC equity investments during the six months ended June 30, 2020 and 2019, and our Jackalope equity investment during the six months ended June 30, 2019 (prior to the acquisition of the remaining 50% equity interest from Williams in April 2019). We amortize the excess basis in certain of our equity investments as an increase in our earnings from unconsolidated affiliates. We recorded amortization of the excess basis in our Tres Holdings equity investment of $0.6 million during both the six months ended June 30, 2020 and 2019. We recorded amortization of the excess basis in our PRBIC equity investment of $0.2 million during the six months ended June 30, 2019. We recorded amortization of the excess basis in the Jackalope equity investment of less than $0.1 million during the six months ended June 30, 2019.

Distributions and Contributions

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

	Distributions(1)				Contributions
	Six Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
Stagecoach Gas	$	30.0	$	25.4	$	—	$	—
Crestwood Permian	6.7		2.9		—		10.0
Tres Holdings	1.4		1.2		6.0		6.3
PRBIC	0.1		—		—		0.2
Jackalope	—		11.6		—		24.4
Total	$	38.2	$	41.1	$	6.0	$	40.9

(1)

In July 2020, we received cash distributions from Stagecoach Gas, Crestwood Permian and Tres Holdings of approximately $14.5 million, $1.8 million and $3.0 million, respectively.

XML

Risk Management (Tables)

6 Months Ended

Jun. 30, 2020

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

Derivatives Not Designated as Hedging Instruments [Table Text Block]

The following table summarizes the impact to our consolidated statements of operations related to our commodity-based derivatives reflected in operating revenues and costs of product/services sold during the three and six months ended June 30, 2020 and 2019 (in millions):

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2020		2019		2020		2019
Product revenues	$	18.0	$	40.2	$	93.0	$	144.3
Gain reflected in costs of product/services sold	$	6.8	$	9.9	$	28.8	$	7.0

Notional Amounts And Terms Of Company's Derivative Financial Instruments

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

	June 30, 2020		December 31, 2019
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, ethane, butane, heating oil and crude oil (MMBbls)	64.4	69.8	33.5	36.6
Natural gas (Bcf)	10.2	17.5	3.7	8.7

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]

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

	June 30, 2020		December 31, 2019
Aggregate fair value of derivative instruments with credit-risk-related contingent features(1)	$	20.3	$	1.6
NYMEX-related net derivative asset (liability) position	$	1.9	$	(28.8	)
NYMEX-related cash collateral posted	$	26.8	$	40.4
Cash collateral received, net	$	21.1	$	16.9

(1)

At June 30, 2020 and December 31, 2019, we posted less than $0.1 million of collateral associated with these derivatives.

XML

Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2020

Fair Value Disclosures [Abstract]

Schedule of Carrying Values and Estimated Fair Values of Debt Instruments

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, 2020				December 31, 2019
	Carrying  Amount		Fair Value		Carrying  Amount		Fair Value
2023 Senior Notes	$	695.9	$	623.0	$	695.1	$	714.0
2025 Senior Notes	$	495.0	$	435.0	$	494.4	$	514.4
2027 Senior Notes	$	592.6	$	499.2	$	592.1	$	610.1

Assets And Liabilities Measured At Fair Value On Recurring Basis

The following tables set forth by level within the fair value hierarchy, our financial instruments that were accounted for at fair value on a recurring basis at June 30, 2020 and December 31, 2019 (in millions):

	June 30, 2020
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting(1)			Collateral/Margin Received or Paid		Fair Value
Assets
Assets from price risk management	$	26.2	$	187.8	$	—	$	214.0	$	(186.3	)	$	16.7	$	44.4
Suburban Propane Partners, L.P. units(2)	2.0		—		—		2.0		—			—		2.0
Total assets at fair value	$	28.2	$	187.8	$	—	$	216.0	$	(186.3	)	$	16.7	$	46.4
Liabilities
Liabilities from price risk management	$	29.7	$	177.8	$	—	$	207.5	$	(186.3	)	$	11.0	$	32.2
Total liabilities at fair value	$	29.7	$	177.8	$	—	$	207.5	$	(186.3	)	$	11.0	$	32.2

	December 31, 2019
	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	$	3.7	$	164.0	$	—	$	167.7	$	(122.3	)	$	(2.2	)	$	43.2
Suburban Propane Partners, L.P. units(2)	3.1		—		—		3.1		—			—			3.1
Total assets at fair value	$	6.8	$	164.0	$	—	$	170.8	$	(122.3	)	$	(2.2	)	$	46.3
Liabilities
Liabilities from price risk management	$	2.8	$	151.9	$	—	$	154.7	$	(122.3	)	$	(25.7	)	$	6.7
Total liabilities at fair value	$	2.8	$	151.9	$	—	$	154.7	$	(122.3	)	$	(25.7	)	$	6.7

(1) Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions.

(2)

Amount is reflected in other assets on CEQP’s consolidated balance sheets.

XML

Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2020

Text Block [Abstract]

Components Of Long-Term Debt

Long-term debt consisted of the following at June 30, 2020 and December 31, 2019 (in millions):

	June 30, 2020		December 31, 2019
Credit Facility	$	801.2	$	557.0
2023 Senior Notes	700.0		700.0
2025 Senior Notes	500.0		500.0
2027 Senior Notes	600.0		600.0
Other	0.6		0.6
Less: deferred financing costs, net	25.9		29.1
Total debt	2,575.9		2,328.5
Less: current portion	0.2		0.2
Total long-term debt, less current portion	$	2,575.7	$	2,328.3

XML

Earnings Per Limited Partner Unit (Tables)

6 Months Ended

Jun. 30, 2020

Earnings Per Share [Abstract]

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]

The following table summarizes information regarding the weighted-average of common units excluded during the three and six months ended June 30, 2020 and 2019 (in millions):

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Preferred units (1)	7.1	—	7.1	7.1
Crestwood Niobrara’s preferred units(1)	8.2	—	8.2	—
Unit-based compensation performance units(1)	0.2	—	0.3	—
Subordinated units(1)	0.4	—	0.4	—

(1) For additional information regarding the potential conversion/redemption of our preferred units and Crestwood Niobrara’s preferred units to CEQP common units, and of our performance units and subordinated units, see our 2019 Annual Report on Form 10-K.

The table below shows CEQP’s net income per limited partner unit based on the number of basic and diluted limited partner units outstanding for the three and six months ended June 30, 2020 and 2019 (in millions, except for per unit data):

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2020			2019		2020			2019
Common unitholders’ interest in net income (loss)	$	(49.5	)	$	198.2	$	(97.8	)	$	193.3
Dilutive effect of net income attributable to preferred units	—			15.0		—			—
Dilutive effect of net income attributable to subordinated units	—			1.2		—			1.2
Diluted net income (loss)	$	(49.5	)	$	214.4	$	(97.8	)	$	194.5
Weighted-average limited partners’ units outstanding - basic	73.2			71.8		73.0			71.8
Dilutive effect of preferred units	—			7.1		—			—
Dilutive effect of Crestwood Niobrara preferred units	—			3.4		—			4.5
Dilutive effect of stock-based compensation performance units	—			0.3		—			0.3
Dilutive effect of subordinated units	—			0.4		—			0.4
Weighted-average limited partners’ units outstanding - diluted	73.2			83.0		73.0			77.0
Basic earnings per unit:
Net income (loss) per limited partner unit	$	(0.68	)	$	2.76	$	(1.34	)	$	2.69
Diluted earnings per unit:
Net income (loss) per limited partner unit	$	(0.68	)	$	2.58	$	(1.34	)	$	2.53

XML

Partners' Capital (Tables)

6 Months Ended

Jun. 30, 2020

Statement of Partners' Capital [Abstract]

Schedule of Distributions Made to Members or Limited Partners, by Distribution

A summary of CEQP’s limited partner quarterly cash distributions for the six months ended June 30, 2020 and 2019 is presented below:

Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2020
February 7, 2020	February 14, 2020	$	0.625	$	45.3
May 8, 2020	May 15, 2020	0.625		45.7
				$	91.0
2019
February 7, 2019	February 14, 2019	$	0.60	$	43.1
May 8, 2019	May 15, 2019	0.60		43.1
				$	86.2

Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Table Text Block]

The following table shows the change in our non-controlling interest in subsidiary at June 30, 2020 and 2019 (in millions):

Balance at December 31, 2019	$	426.2
Contributions from non-controlling partner	2.8
Distributions to non-controlling partner	(18.5		)
Net income attributable to non-controlling partner	20.1
Balance at June 30, 2020	$	430.6

XML

Commitments and Contingencies (Tables)

6 Months Ended

Jun. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

Purchase Commitment, Excluding Long-term Commitment [Table Text Block]

The following table summarizes CEQP’s and CMLP’s self-insurance reserves at June 30, 2020 and December 31, 2019 (in millions):

	CEQP				CMLP
	June 30, 2020		December 31, 2019		June 30, 2020		December 31, 2019
Self-insurance reserves(1)	$	9.4	$	9.7	$	8.3	$	8.3

(1)

At June 30, 2020, CEQP and CMLP classified approximately $6.2 million and $5.2 million, respectively of these reserves as other long-term liabilities on their consolidated balance sheets.

Assets And Liabilities, Lessee [Table Text Block]

The following table summarizes the balance sheet information related to our operating and finance leases at June 30, 2020 and December 31, 2019 (in millions):

	June 30,		December 31,
	2020		2019
Operating Leases
Operating lease right-of-use assets, net	$	44.2	$	53.8
Accrued expenses and other liabilities	$	17.8	$	18.1
Long-term operating lease liabilities	32.9		41.5
Total operating lease liabilities	$	50.7	$	59.6
Finance Leases
Property, plant and equipment	$	14.9	$	14.9
Less: accumulated depreciation	7.2		5.4
Property, plant and equipment, net	$	7.7	$	9.5
Accrued expenses and other liabilities	$	3.3	$	3.2
Other long-term liabilities	3.6		5.2
Total finance lease liabilities	$	6.9	$	8.4

XML

Related Party Transactions (Tables)

6 Months Ended

Jun. 30, 2020

Related Party Transactions [Abstract]

Schedule of Related Party Transactions

The following table shows transactions with our affiliates which are reflected in our consolidated statements of operations (in millions). For a further description of our related party agreements, see our 2019 Annual Report on Form 10-K.

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2020			2019			2020		2019
Revenues at CEQP and CMLP(1)	$	7.5		$	1.3		$	15.0	$	2.5
Costs of product/services sold at CEQP and CMLP(2)	$	3.6		$	0.9		$	6.8	$	35.3
Operations and maintenance expenses charged by CEQP and CMLP(3)	$	5.5		$	5.9		$	11.7	$	13.4
General and administrative expenses charged by CEQP to CMLP, net(4)	$	10.9		$	10.1		$	18.0	$	21.1
General and administrative expenses at CEQP charged to (from) Crestwood Holdings, net(5)	$	(1.5	)	$	(0.1	)	$	11.3	$	(5.3	)

(1) Includes $7.5 million and $15.0 million during the three and six months ended June 30, 2020 related to the sale of NGLs to a subsidiary of Crestwood Permian and $1.3 million and $2.5 million during the three and six months ended June 30, 2019 related to the sale of natural gas to a subsidiary of Stagecoach Gas.

(2) Includes (i) $3.2 million and $6.4 million during the three and six months ended June 30, 2020 and $0.9 million and $9.1 million during the three and six months ended June 30, 2019 related to purchases of NGLs from a subsidiary of Crestwood Permian; (ii) $0.1 million during both the three and six months ended June 30, 2020 related to purchases from a subsidiary of Tres Palacios Holdings, (iii) less than $0.1 million and $2.3 million during the three and six months ended June 30, 2019 related to purchases of natural gas from a subsidiary of Stagecoach Gas; and (iv) $0.3 million during both the three and six months ended June 30, 2020 and less than $0.1 million and $23.9 million during the three and six months ended June 30, 2019 related to an agency marketing agreement with Ascent Resources - Utica, LLC, an affiliate of Crestwood Holdings.

(3) We have operating agreements with certain of our unconsolidated affiliates pursuant to which we charge them operations and maintenance expenses in accordance with their respective agreements, and these charges are reflected as a reduction of operations and maintenance expenses in our consolidated statements of operations. During the three and six months ended June 30, 2020, we charged $1.6 million and $3.3 million to Stagecoach Gas, $1.1 million and $2.2 million to Tres Palacios, and $2.8 million and $6.2 million to Crestwood Permian under these agreements. During the three and six months ended June 30, 2019, we charged $1.9 million and $3.9 million to Stagecoach Gas, $1.0 million and $2.2 million to Tres Palacios, and $3.0 million and $6.8 million to Crestwood Permian. During the six months ended June 30, 2019, we charged $0.5 million to Jackalope under an operating agreement prior to our acquisition of the remaining 50% equity interest in Jackalope in Williams.

(4) Includes $11.9 million and $20.1 million of unit-based compensation charges allocated from CEQP to CMLP for the three and six months ended June 30, 2020 and $11.0 million and $22.9 million for the three and six months ended June 30, 2019. In addition, includes $1.0 million and $2.1 million of CMLP’s general and administrative costs allocated to CEQP during the three and six months ended June 30, 2020 and $0.9 million and $1.8 million during the three and six months ended June 30, 2019.

(5)

Includes $1.7 million of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the three months ended June 30, 2020, a $10.9 million reduction of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the six months ended June 30, 2020 and $0.2 million and $5.6 million of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the three and six months ended June 30, 2019. In addition, includes $0.2 million and $0.4 million of CEQP’s general and administrative costs allocated to Crestwood Holdings during the three and six months ended June 30, 2020 and $0.1 million and $0.3 million during the three and six months ended June 30, 2019.

Schedule of Related Party Receivables and Payables

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

	June 30, 2020		December 31, 2019
Accounts receivable at CEQP and CMLP	$	10.9	$	7.3
Accounts payable at CEQP	$	6.9	$	15.6
Accounts payable at CMLP	$	4.5	$	13.1

XML

Segments (Tables)

6 Months Ended

Jun. 30, 2020

Segment Reporting, Other Significant Reconciling Item [Line Items]

Reconciliation of Net Income (Loss) to Earnings Before Interest, Taxes, Depreciation and Amortization

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

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2020			2019		2020			2019
Net income (loss)	$	(24.3	)	$	225.0	$	(47.7	)	$	239.1
Add:
Interest and debt expense, net	34.0			27.8		66.6			52.7
Provision (benefit) for income taxes	(0.1		)	0.3		(0.1		)	0.3
Depreciation, amortization and accretion	61.0			49.3		117.1			89.1
EBITDA	$	70.6		$	302.4	$	135.9		$	381.2

Summary Of Segment Information

The following tables summarize CEQP’s and CMLP’s reportable segment data for the three and six months ended June 30, 2020 and 2019 (in millions). Intersegment revenues included in the following tables are accounted for as arms-length transactions that apply our revenue recognition policies as described in our 2019 Annual Report on Form 10-K. Included in earnings from unconsolidated affiliates, net below was approximately $9.5 million and $10.3 million of our proportionate share of interest expense, depreciation and amortization expense and gains (losses) on long-lived assets, net recorded by our equity investments for the three months ended June 30, 2020 and 2019 and $23.3 million and $23.0 million for the six months ended June 30, 2020 and 2019.

Crestwood Equity

	Three Months Ended June 30, 2020
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	114.5		$	3.1	$	235.1		$	—		$	352.7
Intersegment revenues	14.3			2.4		(16.7		)	—			—
Costs of product/services sold	21.3			0.1		204.3			—			225.7
Operations and maintenance expense	19.3			0.7		11.6			—			31.6
General and administrative expense	—			—		—			29.5			29.5
Loss on long-lived assets, net	(3.6		)	—		(0.2		)	—			(3.8		)
Earnings (loss) from unconsolidated affiliates, net	(1.0		)	9.4		—			—			8.4
Other income, net	—			—		—			0.1			0.1
EBITDA	$	83.6		$	14.1	$	2.3		$	(29.4	)	$	70.6
Goodwill	$	45.9		$	—	$	92.7		$	—		$	138.6
Total assets	$	3,589.8		$	964.7	$	736.9		$	32.3		$	5,323.7

	Three Months Ended June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	199.7		$	4.9	$	478.8		$	—		$	683.4
Intersegment revenues	25.4			3.2		(28.6		)	—			—
Costs of product/services sold	108.9			—		428.3			—			537.2
Operations and maintenance expense	24.6			0.9		9.2			—			34.7
General and administrative expense	—			—		—			22.3			22.3
Gain (loss) on long-lived assets, net	(0.2		)	—		—			0.2			—
Gain on acquisition	209.4			—		—			—			209.4
Earnings (loss) from unconsolidated affiliates, net	(2.8		)	6.5		—			—			3.7
Other income, net	—			—		—			0.1			0.1
EBITDA	$	298.0		$	13.7	$	12.7		$	(22.0	)	$	302.4

	Six Months Ended June 30, 2020
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	329.4		$	6.6	$	744.6		$	—		$	1,080.6
Intersegment revenues	54.3			5.0		(59.3		)	—			—
Costs of product/services sold	129.6			0.3		630.2			—			760.1
Operations and maintenance expense	46.3			2.1		20.8			—			69.2
General and administrative expense	—			—		—			44.4			44.4
Loss on long-lived assets, net	(4.6		)	—		(0.2		)	—			(4.8		)
Goodwill impairment	(80.3		)	—		—			—			(80.3		)
Earnings (loss) from unconsolidated affiliates, net	(0.2		)	14.1		—			—			13.9
Other income, net	—			—		—			0.2			0.2
EBITDA	$	122.7		$	23.3	$	34.1		$	(44.2	)	$	135.9
Goodwill	$	45.9		$	—	$	92.7		$	—		$	138.6
Total assets	$	3,589.8		$	964.7	$	736.9		$	32.3		$	5,323.7

	Six Months Ended June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	382.0		$	12.7	$	1,123.9		$	—		$	1,518.6
Intersegment revenues	78.2			6.8		(85.0		)	—			—
Costs of product/services sold	246.9			—		985.9			—			1,232.8
Operations and maintenance expense	42.7			1.9		18.7			—			63.3
General and administrative expense	—			—		—			59.5			59.5
Gain (loss) on long-lived assets, net	(2.0		)	—		(0.2		)	0.2			(2.0		)
Gain on acquisition	209.4			—		—			—			209.4
Earnings (loss) from unconsolidated affiliates, net	(3.0		)	13.6		—			—			10.6
Other income, net	—			—		—			0.2			0.2
EBITDA	$	375.0		$	31.2	$	34.1		$	(59.1	)	$	381.2

Crestwood Midstream Partners LP

Segment Reporting, Other Significant Reconciling Item [Line Items]

Reconciliation of Net Income (Loss) to Earnings Before Interest, Taxes, Depreciation and Amortization

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

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2020			2019		2020			2019
Net income (loss)	$	(26.8	)	$	222.9	$	(52.4	)	$	234.5
Add:
Interest and debt expense, net	34.0			27.8		66.6			52.7
Provision (benefit) for income taxes	(0.2		)	0.3		(0.2		)	0.3
Depreciation, amortization and accretion	64.6			52.7		124.2			96.1
EBITDA	$	71.6		$	303.7	$	138.2		$	383.6

Summary Of Segment Information

Crestwood Midstream

	Three Months Ended June 30, 2020
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	114.5		$	3.1	$	235.1		$	—		$	352.7
Intersegment revenues	14.3			2.4		(16.7		)	—			—
Costs of product/services sold	21.3			0.1		204.3			—			225.7
Operations and maintenance expense	19.3			0.7		11.6			—			31.6
General and administrative expense	—			—		—			28.4			28.4
Loss on long-lived assets, net	(3.6		)	—		(0.2		)	—			(3.8		)
Earnings (loss) from unconsolidated affiliates, net	(1.0		)	9.4		—			—			8.4
EBITDA	$	83.6		$	14.1	$	2.3		$	(28.4	)	$	71.6
Goodwill	$	45.9		$	—	$	92.7		$	—		$	138.6
Total assets	$	3,742.1		$	964.7	$	736.9		$	28.6		$	5,472.3

	Three Months Ended June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	199.7		$	4.9	$	478.8		$	—		$	683.4
Intersegment revenues	25.4			3.2		(28.6		)	—			—
Costs of product/services sold	108.9			—		428.3			—			537.2
Operations and maintenance expense	24.6			0.9		9.2			—			34.7
General and administrative expense	—			—		—			20.9			20.9
Gain (loss) on long-lived assets, net	(0.2		)	—		—			0.2			—
Gain on acquisition	209.4			—		—			—			209.4
Earnings (loss) from unconsolidated affiliates, net	(2.8		)	6.5		—			—			3.7
EBITDA	$	298.0		$	13.7	$	12.7		$	(20.7	)	$	303.7

	Six Months Ended June 30, 2020
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	329.4		$	6.6	$	744.6		$	—		$	1,080.6
Intersegment revenues	54.3			5.0		(59.3		)	—			—
Costs of product/services sold	129.6			0.3		630.2			—			760.1
Operations and maintenance expense	46.3			2.1		20.8			—			69.2
General and administrative expense	—			—		—			41.9			41.9
Loss on long-lived assets, net	(4.6		)	—		(0.2		)	—			(4.8		)
Goodwill impairment	(80.3		)	—		—			—			(80.3		)
Earnings (loss) from unconsolidated affiliates, net	(0.2		)	14.1		—			—			13.9
EBITDA	$	122.7		$	23.3	$	34.1		$	(41.9	)	$	138.2
Goodwill	$	45.9		$	—	$	92.7		$	—		$	138.6
Total assets	$	3,742.1		$	964.7	$	736.9		$	28.6		$	5,472.3

	Six Months Ended June 30, 2019
	Gathering and Processing			Storage and Transportation		Marketing, Supply and Logistics			Corporate			Total
Revenues	$	382.0		$	12.7	$	1,123.9		$	—		$	1,518.6
Intersegment revenues	78.2			6.8		(85.0		)	—			—
Costs of product/services sold	246.9			—		985.9			—			1,232.8
Operations and maintenance expense	42.7			1.9		18.7			—			63.3
General and administrative expense	—			—		—			56.9			56.9
Gain (loss) on long-lived assets, net	(2.0		)	—		(0.2		)	0.2			(2.0		)
Gain on acquisition	209.4			—		—			—			209.4
Earnings (loss) from unconsolidated affiliates, net	(3.0		)	13.6		—			—			10.6
EBITDA	$	375.0		$	31.2	$	34.1		$	(56.7	)	$	383.6

XML

Revenue Recognition (Tables)

6 Months Ended

Jun. 30, 2020

Revenue Recognition [Abstract]

Contract with Customer, Contract Asset, Contract Liability, and Receivable [Table Text Block]

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

	June 30, 2020		December 31, 2019
Contract assets (non-current)	$	1.2	$	1.2
Contract liabilities (current)(1)	$	10.2	$	8.8
Contract liabilities (non-current)(1)	$	159.6	$	144.7

(1)

During the three and six months ended June 30, 2020, we recognized revenues of approximately $3.1 million and $6.9 million that were previously included in contract liabilities (current) at December 31, 2019. The remaining change in our contract liabilities during the three and six months ended June 30, 2020, related to capital reimbursements associated with our revenue contracts and revenue deferrals associated with our contracts with increasing (decreasing) rates.

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]

The following table summarizes the transaction price allocated to our remaining performance obligations under certain contracts that have not been recognized as of June 30, 2020 (in millions):

Remainder of 2020	$	52.3
2021	94.1
2022	63.2
2023	8.0
2024	3.3
Total	$	220.9

Disaggregation of Revenue

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, 2020 and 2019 (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.

	Three Months Ended June 30, 2020
	Gathering and Processing		Storage and Transportation		Marketing, Supply and Logistics		Intersegment Elimination			Total
Topic 606 revenues
Gathering
Natural gas	$	33.2	$	—	$	—	$	—		$	33.2
Crude oil	17.9		—		—		—			17.9
Water	18.3		—		—		—			18.3
Processing
Natural gas	7.1		—		—		—			7.1
Compression
Natural gas	5.7		—		—		—			5.7
Storage
Crude oil	0.4		1.1		—		(0.8		)	0.7
NGLs	—		—		3.6		—			3.6
Pipeline
Crude oil	—		1.3		—		(0.4		)	0.9
NGLs	—		—		0.2		—			0.2
Transportation
Crude oil	1.5		—		0.3		—			1.8
NGLs	—		—		2.6		—			2.6
Rail Loading
Crude oil	—		2.9		—		(1.2		)	1.7
Product Sales
Natural gas	6.9		—		15.5		(6.8		)	15.6
Crude oil	34.8		—		102.0		(7.1		)	129.7
NGLs	3.0		—		92.4		(0.3		)	95.1
Other	—		0.2		0.2		(0.1		)	0.3
Total Topic 606 revenues	128.8		5.5		216.8		(16.7		)	334.4
Non-Topic 606 revenues(1)	—		—		18.3		—			18.3
Total revenues	$	128.8	$	5.5	$	235.1	$	(16.7	)	$	352.7

(1) Represents revenues primarily related to our commodity-based derivatives. See Note 6 for additional information related to our price risk management activities.

	Three Months Ended June 30, 2019
	Gathering and Processing		Storage and Transportation		Marketing, Supply and Logistics		Intersegment Elimination			Total
Topic 606 revenues
Gathering
Natural gas	$	42.9	$	—	$	—	$	—		$	42.9
Crude oil	15.1		—		—		—			15.1
Water	19.0		—		—		—			19.0
Processing
Natural gas	8.1		—		—		—			8.1
Compression
Natural gas	6.2		—		—		—			6.2
Storage
Crude oil	0.5		1.5		—		(0.5		)	1.5
NGLs	—		—		1.3		—			1.3
Pipeline
Crude oil	—		1.5		—		(0.5		)	1.0
Transportation
Crude oil	1.8		—		1.5		—			3.3
NGLs	—		—		2.1		—			2.1
Rail Loading
Crude oil	—		3.9		—		(1.4		)	2.5
Product Sales
Natural gas	10.9		—		7.9		(4.8		)	14.0
Crude oil	110.2		—		291.4		(16.0		)	385.6
NGLs	10.4		—		133.9		(4.5		)	139.8
Other	—		1.2		0.3		(0.9		)	0.6
Total Topic 606 revenues	225.1		8.1		438.4		(28.6		)	643.0
Non-Topic 606 revenues(1)	—		—		40.4		—			40.4
Total revenues	$	225.1	$	8.1	$	478.8	$	(28.6	)	$	683.4

(1) Represents revenues primarily related to our commodity-based derivatives. See Note 6 for additional information related to our price risk management activities.

	Six Months Ended June 30, 2020
	Gathering and Processing		Storage and Transportation		Marketing, Supply and Logistics		Intersegment Elimination			Total
Topic 606 revenues
Gathering
Natural gas	$	77.0	$	—	$	—	$	—		$	77.0
Crude oil	44.4		—		—		—			44.4
Water	41.3		—		—		—			41.3
Processing
Natural gas	17.3		—		—		—			17.3
Compression
Natural gas	12.0		—		—		—			12.0
Storage
Crude oil	0.9		1.7		—		(1.2		)	1.4
NGLs	—		—		5.2		—			5.2
Pipeline
Crude oil	—		2.9		—		(0.9		)	2.0
NGLs	—		—		0.2		—			0.2
Transportation
Crude oil	3.5		—		1.9		—			5.4
NGLs	—		—		4.3		—			4.3
Rail Loading
Crude oil	—		6.3		—		(2.6		)	3.7
Product Sales
Natural gas	18.9		—		33.8		(18.5		)	34.2
Crude oil	155.9		—		352.2		(23.4		)	484.7
NGLs	12.5		—		252.7		(12.2		)	253.0
Other	—		0.7		0.7		(0.5		)	0.9
Total Topic 606 revenues	383.7		11.6		651.0		(59.3		)	987.0
Non-Topic 606 revenues(1)	—		—		93.6		—			93.6
Total revenues	$	383.7	$	11.6	$	744.6	$	(59.3	)	$	1,080.6

(1) Represents revenues primarily related to our commodity-based derivatives. See Note 6 for additional information related to our price risk management activities.

	Six Months Ended June 30, 2019
	Gathering and Processing		Storage and Transportation		Marketing, Supply and Logistics		Intersegment Elimination			Total
Topic 606 revenues
Gathering
Natural gas	$	73.1	$	—	$	—	$	—		$	73.1
Crude oil	30.4		—		—		—			30.4
Water	35.8		—		—		—			35.8
Processing
Natural gas	10.6		—		—		—			10.6
Compression
Natural gas	12.2		—		—		—			12.2
Storage
Crude oil	1.0		2.9		—		(1.2		)	2.7
NGLs	—		—		2.6		—			2.6
Pipeline
Crude oil	—		3.2		—		(1.2		)	2.0
Transportation
Crude oil	3.3		—		3.0		—			6.3
NGLs	—		—		6.2		—			6.2
Rail Loading
Crude oil	—		11.1		—		(2.8		)	8.3
Product Sales
Natural gas	29.7		—		30.2		(11.4		)	48.5
Crude oil	241.8		—		581.5		(59.3		)	764.0
NGLs	22.3		—		355.4		(7.3		)	370.4
Other	—		2.3		0.3		(1.8		)	0.8
Total Topic 606 revenues	460.2		19.5		979.2		(85.0		)	1,373.9
Non-Topic 606 revenues(1)	—		—		144.7		—			144.7
Total revenues	$	460.2	$	19.5	$	1,123.9	$	(85.0	)	$	1,518.6

(1)

Represents revenues primarily related to our commodity-based derivatives. See Note 6 for additional information related to our price risk management activities.

XML

Condensed Consolidating Financial Information (Tables)

6 Months Ended

Jun. 30, 2020

Condensed Financial Information Disclosure [Abstract]

Condensed Balance Sheet

Crestwood Midstream Partners LP
Condensed Consolidating Balance Sheet
June 30, 2020
(in millions)
(unaudited)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	0.4	$	—	$	5.7	$	—		$	6.1
Accounts receivable	—		146.5		19.3		—			165.8
Inventory	—		88.9		—		—			88.9
Other current assets	—		52.8		0.3		—			53.1
Total current assets	0.4		288.2		25.3		—			313.9
Property, plant and equipment, net	—		2,410.1		783.6		—			3,193.7
Goodwill and intangible assets, net	—		671.2		284.5		—			955.7
Operating lease right-of-use assets, net	—		41.5		2.7		—			44.2
Investments in consolidated affiliates	4,501.0		—		—		(4,501.0		)	—
Investments in unconsolidated affiliates	—		—		961.9		—			961.9
Other non-current assets	—		2.4		0.5		—			2.9
Total assets	$	4,501.4	$	3,413.4	$	2,058.5	$	(4,501.0	)	$	5,472.3
Liabilities and capital
Current liabilities:
Accounts payable	$	—	$	114.6	$	1.5	$	—		$	116.1
Other current liabilities	25.2		114.8		24.8		—			164.8
Total current liabilities	25.2		229.4		26.3		—			280.9
Long-term liabilities:
Long-term debt, less current portion	2,575.7		—		—		—			2,575.7
Other long-term liabilities	—		165.8		118.2		—			284.0
Deferred income taxes	—		0.6		—		—			0.6
Total liabilities	2,600.9		395.8		144.5		—			3,141.2
Interest of non-controlling partner in subsidiary	—		—		430.6		—			430.6
Partners’ capital	1,900.5		3,017.6		1,483.4		(4,501.0		)	1,900.5
Total liabilities and capital	$	4,501.4	$	3,413.4	$	2,058.5	$	(4,501.0	)	$	5,472.3

Crestwood Midstream Partners LP
Condensed Consolidating Balance Sheet
December 31, 2019
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	1.8	$	—	$	23.6	$	—		$	25.4
Accounts receivable	—		229.1		12.8		—			241.9
Inventory	—		53.7		—		—			53.7
Other current assets	—		54.6		0.2		—			54.8
Total current assets	1.8		337.4		36.6		—			375.8
Property, plant and equipment, net	—		2,331.3		736.2		—			3,067.5
Goodwill and intangible assets, net	—		650.7		373.4		—			1,024.1
Operating lease right-of-use assets, net	—		51.0		2.8		—			53.8
Investments in consolidated affiliates	4,451.6		—		—		(4,451.6		)	—
Investments in unconsolidated affiliates	—		—		980.4		—			980.4
Other non-current assets	—		1.9		0.5		—			2.4
Total assets	$	4,453.4	$	3,372.3	$	2,129.9	$	(4,451.6	)	$	5,504.0
Liabilities and capital
Current liabilities:
Accounts payable	$	—	$	175.9	$	10.7	$	—		$	186.6
Other current liabilities	25.8		123.9		17.6		—			167.3
Total current liabilities	25.8		299.8		28.3		—			353.9
Long-term liabilities:
Long-term debt, less current portion	2,328.3		—		—		—			2,328.3
Other long-term liabilities	—		174.8		120.8		—			295.6
Deferred income taxes	—		0.7		—		—			0.7
Total liabilities	2,354.1		475.3		149.1		—			2,978.5
Interest of non-controlling partner in subsidiary	—		—		426.2		—			426.2
Partners’ capital	2,099.3		2,897.0		1,554.6		(4,451.6		)	2,099.3
Total liabilities and capital	$	4,453.4	$	3,372.3	$	2,129.9	$	(4,451.6	)	$	5,504.0

Condensed Income Statement

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Three Months Ended June 30, 2020
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	336.5		$	16.2		$	—		$	352.7
Costs of product/services sold	—			225.5			0.2			—			225.7
Operating expenses and other:
Operations and maintenance	—			26.5			5.1			—			31.6
General and administrative	14.8			13.6			—			—			28.4
Depreciation, amortization and accretion	—			50.3			14.3			—			64.6
Loss on long-lived assets, net	—			2.0			1.8			—			3.8
	14.8			92.4			21.2			—			128.4
Operating income (loss)	(14.8		)	18.6			(5.2		)	—			(1.4		)
Earnings from unconsolidated affiliates, net	—			—			8.4			—			8.4
Interest and debt expense, net	(33.9		)	(0.1		)	—			—			(34.0		)
Equity in net income (loss) of subsidiaries	11.7			—			—			(11.7		)	—
Income (loss) before income taxes	(37.0		)	18.5			3.2			(11.7		)	(27.0		)
Benefit for income taxes	—			0.2			—			—			0.2
Net income (loss)	(37.0		)	18.7			3.2			(11.7		)	(26.8		)
Net income attributable to non-controlling partner in subsidiary	—			—			10.2			—			10.2
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(37.0	)	$	18.7		$	(7.0	)	$	(11.7	)	$	(37.0	)

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Three Months Ended June 30, 2019
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	663.2		$	20.2		$	—		$	683.4
Costs of product/services sold	—			537.2			—			—			537.2
Operating expenses:
Operations and maintenance	—			27.5			7.2			—			34.7
General and administrative	9.7			11.2			—			—			20.9
Depreciation, amortization and accretion	—			43.0			9.7			—			52.7
Gain on acquisition	—			—			(209.4		)	—			(209.4		)
	9.7			81.7			(192.5		)	—			(101.1		)
Operating income (loss)	(9.7		)	44.3			212.7			—			247.3
Earnings from unconsolidated affiliates, net	—			—			3.7			—			3.7
Interest and debt expense, net	(28.0		)	0.2			—			—			(27.8		)
Equity in net income (loss) of subsidiaries	250.0			—			—			(250.0		)	—
Income (loss) before income taxes	212.3			44.5			216.4			(250.0		)	223.2
Provision for income taxes	—			(0.3		)	—			—			(0.3		)
Net income (loss)	212.3			44.2			216.4			(250.0		)	222.9
Net income attributable to non-controlling partner in subsidiary	—			—			10.6			—			10.6
Net income (loss) attributable to Crestwood Midstream Partners LP	$	212.3		$	44.2		$	205.8		$	(250.0	)	$	212.3

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Six Months Ended June 30, 2020
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	1,036.9		$	43.7		$	—		$	1,080.6
Costs of product/services sold	—			759.9			0.2			—			760.1
Operating expenses and other:
Operations and maintenance	—			58.3			10.9			—			69.2
General and administrative	32.7			9.2			—			—			41.9
Depreciation, amortization and accretion	—			98.1			26.1			—			124.2
Loss on long-lived assets, net	—			3.0			1.8			—			4.8
Goodwill impairment	—			—			80.3			—			80.3
	32.7			168.6			119.1			—			320.4
Operating income (loss)	(32.7		)	108.4			(75.6		)	—			0.1
Earnings from unconsolidated affiliates, net	—			—			13.9			—			13.9
Interest and debt expense, net	(66.3		)	(0.3		)	—			—			(66.6		)
Equity in net income (loss) of subsidiaries	26.5			—			—			(26.5		)	—
Income (loss) before income taxes	(72.5		)	108.1			(61.7		)	(26.5		)	(52.6		)
Benefit for income taxes	—			0.2			—			—			0.2
Net income (loss)	(72.5		)	108.3			(61.7		)	(26.5		)	(52.4		)
Net income attributable to non-controlling partner	—			—			20.1			—			20.1
Net income (loss) attributable to Crestwood Midstream Partners LP	$	(72.5	)	$	108.3		$	(81.8	)	$	(26.5	)	$	(72.5	)

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Operations
Six Months Ended June 30, 2019
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	1,498.4		$	20.2		$	—		$	1,518.6
Costs of product/services sold	—			1,232.8			—			—			1,232.8
Operating expenses and other:
Operations and maintenance	—			56.1			7.2			—			63.3
General and administrative	28.4			28.5			—			—			56.9
Depreciation, amortization and accretion	—			86.4			9.7			—			96.1
Loss on long-lived assets, net	—			2.0			—			—			2.0
Gain on acquisition	—			—			(209.4		)	—			(209.4		)
	28.4			173.0			(192.5		)	—			8.9
Operating income (loss)	(28.4		)	92.6			212.7			—			276.9
Earnings from unconsolidated affiliates, net	—			—			10.6			—			10.6
Interest and debt expense, net	(52.7		)	—			—			—			(52.7		)
Equity in net income (loss) of subsidiaries	301.0			—			—			(301.0		)	—
Income (loss) before income taxes	219.9			92.6			223.3			(301.0		)	234.8
Provision for income taxes	—			(0.3		)	—			—			(0.3		)
Net income (loss)	219.9			92.3			223.3			(301.0		)	234.5
Net income attributable to non-controlling partner in subsidiary	—			—			14.6			—			14.6
Net income (loss) attributable to Crestwood Midstream Partners LP	$	219.9		$	92.3		$	208.7		$	(301.0	)	$	219.9

Condensed Cash Flow Statement

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2020
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities	$	(96.4	)	$	197.4		$	80.1		$	—		$	181.1
Cash flows from investing activities:
Acquisition, net of cash acquired	—			(162.3		)	—			—			(162.3		)
Purchases of property, plant and equipment	—			(56.2		)	(87.0		)	—			(143.2		)
Investment in unconsolidated affiliates	—			—			(6.0		)	—			(6.0		)
Capital distributions from unconsolidated affiliates	—			—			18.9			—			18.9
Capital distributions from consolidated affiliates	8.2			—			—			(8.2		)	—
Other	—			(0.3		)	—			—			(0.3		)
Net cash provided by (used in) investing activities	8.2			(218.8		)	(74.1		)	(8.2		)	(292.9		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	742.5			—			—			—			742.5
Payments on long-term debt	(498.2		)	—			—			—			(498.2		)
Payments on finance leases	—			(1.6		)	—			—			(1.6		)
Net proceeds from issuance of non-controlling interest	—			—			2.8			—			2.8
Distributions to partners	(119.0		)	—			(18.5		)	—			(137.5		)
Distributions to parent	—			—			(8.2		)	8.2			—
Taxes paid for unit-based compensation vesting	—			(15.5		)	—			—			(15.5		)
Change in intercompany balances	(38.5		)	38.5			—			—			—
Net cash provided by (used in) financing activities	86.8			21.4			(23.9		)	8.2			92.5
Net change in cash	(1.4		)	—			(17.9		)	—			(19.3		)
Cash at beginning of period	1.8			—			23.6			—			25.4
Cash at end of period	$	0.4		$	—		$	5.7		$	—		$	6.1

Crestwood Midstream Partners LP
Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2019
(in millions)
(unaudited)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities	$	(87.1	)	$	309.5		$	(27.3	)	$	—		$	195.1
Cash flows from investing activities:
Acquisition, net of cash acquired	—			—			(462.1		)	—			(462.1		)
Purchases of property, plant and equipment	—			(127.7		)	(77.0		)	—			(204.7		)
Investment in unconsolidated affiliates	—			—			(40.9		)	—			(40.9		)
Capital distributions from unconsolidated affiliates	—			—			24.2			—			24.2
Capital contributions to consolidated affiliates	(217.1		)	—			—			217.1			—
Other	—			(0.5		)	—			—			(0.5		)
Net cash provided by (used in) investing activities	(217.1		)	(128.2		)	(555.8		)	217.1			(684.0		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	1,544.0			—			—			—			1,544.0
Payments on long-term debt	(1,159.1		)	(0.4		)	—			—			(1,159.5		)
Payments on finance leases	—			(1.9		)	—			—			(1.9		)
Payments for debt-related deferred costs	(9.0		)	—			—			—			(9.0		)
Net proceeds from the issuance of non-controlling interest	—			—			235.0			—			235.0
Distributions to partners	(117.5		)	—			(6.6		)	—			(124.1		)
Contributions from parent	—			—			217.1			(217.1		)	—
Taxes paid for unit-based compensation vesting	—			(10.6		)	—			—			(10.6		)
Change in intercompany balances	30.7			(168.4		)	137.7			—			—
Net cash provided by (used in) financing activities	289.1			(181.3		)	583.2			(217.1		)	473.9
Net change in cash	(15.1		)	—			0.1			—			(15.0		)
Cash at beginning of period	16.5			—			—			—			16.5
Cash at end of period	$	1.4		$	—		$	0.1		$	—		$	1.5

XML

Basis of Presentation and Summary of Significant Accounting Policies (Details) - USD ($) $ in Millions		3 Months Ended			6 Months Ended
	Jan. 01, 2020	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Goodwill [Roll Forward]
Goodwill, beginning balance	$ 218.9		$ 218.9		$ 218.9
Goodwill impairment		$ 0.0		$ 0.0	80.3	$ 0.0
Goodwill, ending balance		138.6			138.6
Allowance for doubtful accounts		0.6			0.6		$ 0.3
Investments in unconsolidated affiliates		$ 961.9			$ 961.9		980.4
Accounting Standards Update [Extensible List]	us-gaap:AccountingStandardsUpdate201613Member
Crestwood Permian Basin Holdings LLC
Goodwill [Roll Forward]
Ownership percentage	50.00%	50.00%			50.00%
Investments in unconsolidated affiliates		$ 114.7			$ 114.7		$ 121.8
Arrow
Goodwill [Roll Forward]
Goodwill, beginning balance	$ 45.9		45.9		45.9
Goodwill impairment					0.0
Goodwill, ending balance		45.9			45.9
Powder River Basin
Goodwill [Roll Forward]
Goodwill, beginning balance	80.3		80.3		80.3
Goodwill impairment			80.3		80.3
Goodwill, ending balance		0.0			0.0
NGL Marketing and Logistics
Goodwill [Roll Forward]
Goodwill, beginning balance	92.7		$ 92.7		92.7
Goodwill impairment					0.0
Goodwill, ending balance		$ 92.7			$ 92.7
Cumulative Effect, Period of Adoption, Adjustment
Goodwill [Roll Forward]
Allowance for doubtful accounts	0.7
Partners' capital	0.7
Cumulative Effect, Period of Adoption, Adjustment | Crestwood Permian Basin Holdings LLC
Goodwill [Roll Forward]
Partners' capital	(0.2)
Investments in unconsolidated affiliates	$ 0.2

XML

Acquisitions Acquisitions (Details) $ in Millions		1 Months Ended		3 Months Ended		6 Months Ended
	Apr. 09, 2019 USD ($)	Apr. 30, 2020 USD ($) Terminals MMBbls	Apr. 30, 2019 USD ($)	Jun. 30, 2020 USD ($)	Jun. 30, 2019 USD ($)	Jun. 30, 2020 USD ($)	Jun. 30, 2019 USD ($)
Business Acquisition [Line Items]
Net proceeds from issuance of non-controlling interest						$ 2.8	$ 235.0
Gain on acquisition				$ 0.0	$ 209.4	$ 0.0	$ 209.4
Crestwood Niobrara LLC
Business Acquisition [Line Items]
Net proceeds from issuance of non-controlling interest			$ 235.0
Percentage of voting rights acquired	100.00%
Crestwood Niobrara LLC | Williams Partners LP
Business Acquisition [Line Items]
Additional voting rights acquired	50.00%
Percentage of voting rights acquired	100.00%
Jackalope Gas Gathering Services, L.L.C.
Business Acquisition [Line Items]
Ownership percentage			50.00%		50.00%		50.00%
Plains All American Pipeline, L.P.
Business Acquisition [Line Items]
Consideration transferred		$ 162.0
NGL Storage Capacity | MMBbls		7
Liquid Petroleum Gas Terminals | Terminals		7
Property plant and equipment		$ 160.0
Assets and liabilities, net		$ 2.0
Jackalope Gas Gathering Services, L.L.C.
Business Acquisition [Line Items]
Consideration transferred	$ 484.6

XML

Certain Balance Sheet Information (Accrued Expenses and Other Liabilities) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019	Jun. 30, 2019	Apr. 30, 2019
Accrued Expenses and Other Liabilities [Line Items]
Contract Liabilities (Non-current)	$ 159.6	$ 144.7
Accrued expenses	35.1	61.6
Accrued property taxes	8.2	6.1
Tax payable	0.3	0.3
Interest payable	25.0	25.6
Accrued additions to property, plant and equipment	14.9	38.0
Business Combination, Contingent Consideration, Liability, Current	19.0	0.0
Operating Lease, Liability, Current	17.8	18.1
Capital leases		3.2
Finance Lease, Liability, Current	3.3
Deferred Revenue	10.2	8.8
Total accrued expenses and other liabilities	133.8	161.7
Business Combination, Contingent Consideration, Liability, Noncurrent	38.0	57.0
Long-term operating lease liabilities	32.9	41.5
Asset Retirement Obligations, Noncurrent	34.6	33.3
Other long-term liabilities	285.7	301.6
Crestwood Midstream Partners LP
Accrued Expenses and Other Liabilities [Line Items]
Contract Liabilities (Non-current)	159.6
Accrued expenses	33.7	60.3
Accrued property taxes	8.2	6.1
Tax payable	0.3	0.3
Interest payable	25.0	25.6
Accrued additions to property, plant and equipment	14.9	38.0
Business Combination, Contingent Consideration, Liability, Current	19.0	0.0
Operating Lease, Liability, Current	17.8	18.1
Capital leases		3.2
Finance Lease, Liability, Current	3.3
Deferred Revenue	10.2	8.8
Total accrued expenses and other liabilities	132.4	160.4
Business Combination, Contingent Consideration, Liability, Noncurrent	38.0
Long-term operating lease liabilities	32.9
Asset Retirement Obligations, Noncurrent	34.6
Other long-term liabilities	284.0	295.6
Jackalope Gas Gathering Services, L.L.C.
Accrued Expenses and Other Liabilities [Line Items]
Ownership percentage			50.00%	50.00%
Other Noncurrent Liabilities [Member]
Accrued Expenses and Other Liabilities [Line Items]
Other long-term liabilities	20.6	25.1
Other Noncurrent Liabilities [Member] | Crestwood Midstream Partners LP
Accrued Expenses and Other Liabilities [Line Items]
Other long-term liabilities	$ 18.9	$ 19.1

XML

Investments in Unconsolidated Affiliates Net Investments In and Earnings (Loss) from Unconsolidated Affiliates (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Jan. 01, 2020	Dec. 31, 2019	Apr. 30, 2019	Apr. 09, 2019
Schedule of Equity Method Investments [Line Items]
Investment	$ 961.9			$ 961.9			$ 980.4
Earnings from unconsolidated affiliates, net	8.4		$ 3.7	13.9	$ 10.6
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Investment	802.8			802.8			814.4
Earnings from unconsolidated affiliates, net	9.2		6.4	18.4	13.4
Difference between carrying amount and underlying equity	51.3			51.3
Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Investment	0.0			0.0			0.0
Earnings from unconsolidated affiliates, net	0.0		$ 0.5	0.0	$ 3.7
Ownership percentage			50.00%		50.00%			50.00%
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investment	40.6			40.6			35.9
Earnings from unconsolidated affiliates, net	0.1		$ 0.1	0.1	$ 0.3
Difference between carrying amount and underlying equity	23.4			23.4
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Investment	3.8			3.8			8.3
Earnings from unconsolidated affiliates, net	0.1	$ (4.5)	0.0	(4.4)	(0.1)
Difference between carrying amount and underlying equity		$ 5.5
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investment	114.7			114.7			$ 121.8
Earnings from unconsolidated affiliates, net	(1.0)		$ (3.3)	(0.2)	$ (6.7)
Difference between carrying amount and underlying equity	$ 9.7			$ 9.7
Ownership percentage	50.00%			50.00%		50.00%
Crestwood Niobrara LLC
Schedule of Equity Method Investments [Line Items]
Percentage of voting rights acquired									100.00%
Crestwood Niobrara LLC | Williams Partners LP
Schedule of Equity Method Investments [Line Items]
Additional voting rights acquired									50.00%
Percentage of voting rights acquired									100.00%

XML

Investments in Unconsolidated Affiliates Summarized Financial Information (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Apr. 09, 2019
Schedule of Equity Method Investments [Line Items]
Revenues	$ 352.7	$ 683.4	$ 1,080.6	$ 1,518.6
Operating Expenses	125.9	(103.1)	315.8	4.5
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$ (24.3)	$ 225.0	(47.7)	239.1
Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Amortization			0.1
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Amortization			0.6	0.3
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Amortization				0.2
Crestwood Niobrara LLC | Williams Partners LP
Schedule of Equity Method Investments [Line Items]
Additional voting rights acquired					50.00%
Equity Method Investment, Nonconsolidated Investee or Group of Investees [Member]
Schedule of Equity Method Investments [Line Items]
Revenues			129.1	134.5
Operating Expenses			115.0	102.6
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest			15.2	31.0
Equity Method Investment, Nonconsolidated Investee or Group of Investees [Member] | Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Revenues			75.6	79.1
Operating Expenses			38.9	40.4
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest			36.8	38.9
Equity Method Investment, Nonconsolidated Investee or Group of Investees [Member] | Other Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Revenues			53.5	55.4
Operating Expenses			76.1	62.2
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest			$ (21.6)	$ (7.9)

XML

Investments in Unconsolidated Affiliates Distributions and Contributions (Details) - USD ($) $ in Millions	1 Months Ended	6 Months Ended
	Jul. 31, 2020	Jun. 30, 2020	Jun. 30, 2019
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		$ 38.2	$ 41.1
Payments to acquire equity method investments		6.0	40.9
Payments to Acquire Equity Method Investments Cash and Noncash Consideration			40.9
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		30.0	25.4
Payments to acquire equity method investments		0.0	0.0
Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		0.0	11.6
Payments to acquire equity method investments		0.0	24.4
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		6.7	2.9
Payments to acquire equity method investments		0.0	10.0
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		1.4	1.2
Payments to acquire equity method investments		6.0	6.3
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		0.1	0.0
Payments to acquire equity method investments		$ 0.0	$ 0.2
Subsequent Event | Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments	$ 14.5
Subsequent Event | Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments	1.8
Subsequent Event | Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments	$ 3.0

XML

Investments in Unconsolidated Affiliates Narrative (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jan. 01, 2020	Dec. 31, 2019	Apr. 30, 2019
Schedule of Equity Method Investments [Line Items]
Business Combination, Contingent Consideration, Liability, Current	$ 19.0			$ 0.0
Business Combination, Contingent Consideration, Liability, Noncurrent	38.0			57.0
Purchases of property, plant and equipment	143.2	$ 204.7
Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Ownership percentage		50.00%			50.00%
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 10.0
Ownership percentage	50.00%		50.00%
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Business Combination, Contingent Consideration, Liability	$ 57.0
Business Combination, Contingent Consideration, Liability, Noncurrent	$ 38.0
Crestwood Equity Partners LP | Crestwood Permian Basin Holdings
Schedule of Equity Method Investments [Line Items]
Ownership percentage	50.00%
Crestwood Midstream Partners LP
Schedule of Equity Method Investments [Line Items]
Business Combination, Contingent Consideration, Liability, Current	$ 19.0			$ 0.0
Business Combination, Contingent Consideration, Liability, Noncurrent	38.0
Purchases of property, plant and equipment	$ 143.2	$ 204.7

XML

Risk Management (Risk Management Activities) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Revenue	$ 18.0	$ 40.2	$ 93.0	$ 144.3
Commodity contract
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative instruments not designated as hedging	$ 6.8	$ 9.9	$ 28.8	$ 7.0

XML

Risk Management (Notional Amounts and Terms of Company's Derivative Financial Instruments) (Details) bcf in Millions, MMBbls in Millions	Jun. 30, 2020 MMBbls bcf	Dec. 31, 2019 MMBbls bcf
Propane Crude And Heating Oil | Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount | MMBbls	64.4	33.5
Propane Crude And Heating Oil | Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount | MMBbls	69.8	36.6
Natural Gas [Member] | Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount | bcf	10.2	3.7
Natural Gas [Member] | Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount | bcf	17.5	8.7

XML

Risk Management Schedule of Derivative Instruments in Statement of Financial Position, Fair Value (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Derivative [Line Items]
Collateral posted for commodity derivative instruments	$ 21.1	$ 16.9
Commodity contract
Derivative [Line Items]
Collateral posted for commodity derivative instruments	0.1	0.1
NYMEX Derivative Liability
Derivative [Line Items]
Derivative Asset	1.9
Derivative Liability		(28.8)
NYMEX Margin Deposit
Derivative [Line Items]
NYMEX margin deposits	26.8	40.4
Commodity contract with credit contingent features
Derivative [Line Items]
Aggregate fair value of commodity derivative instruments	$ 20.3	$ 1.6

XML

Risk Management (Narrative) (Details) - Price Risk Contracts Member - Maximum	6 Months Ended
	Jun. 30, 2020
Derivative [Line Items]
Remaining maturity	37 months
Percent of contracts expiring in the next twelve months	83.00%

XML

Fair Value Measurements (Schedule of Carrying Values and Estimated Fair Values of Senior Notes) (Details) - Crestwood Midstream Partners LP - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Senior Notes, 2023
Debt Instrument [Line Items]
Carrying amount	$ 695.9	$ 695.1
Fair value	623.0	714.0
Senior Notes, 2025
Debt Instrument [Line Items]
Carrying amount	495.0	494.4
Fair value	435.0	514.4
Senior Notes, due 2027
Debt Instrument [Line Items]
Carrying amount	592.6	592.1
Fair value	$ 499.2	$ 610.1

XML

Fair Value Measurements (Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	$ 214.0	$ 167.7
SPH units	2.0	3.1
Assets, Fair Value Disclosure, Excluding Netting Adjustments	216.0	170.8
Netting agreements	(186.3)	(122.3)
Assets, Collateral/Margin Received or Paid	16.7	2.2
Assets from price risk management, total	44.4	43.2
Total assets at fair value	46.4	46.3
Liabilities from price risk management	207.5	154.7
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	207.5	154.7
Netting agreements	(186.3)	(122.3)
Liabilities, Collateral/Margin Received or Paid	11.0	25.7
Liabilities from price risk management, total	32.2	6.7
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	26.2	3.7
SPH units	2.0	3.1
Assets, Fair Value Disclosure, Excluding Netting Adjustments	28.2	6.8
Liabilities from price risk management	29.7	2.8
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	29.7	2.8
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	187.8	164.0
SPH units	0.0	0.0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	187.8	164.0
Liabilities from price risk management	177.8	151.9
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	177.8	151.9
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	0.0	0.0
SPH units	0.0	0.0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	0.0	0.0
Liabilities from price risk management	0.0	0.0
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	$ 0.0	$ 0.0

XML

Long-Term Debt (Components Of Long-Term Debt) (Details) - USD ($)	Jun. 30, 2020	Dec. 31, 2019	Apr. 30, 2019
Debt Instrument [Line Items]
Deferred finance costs, net	$ 25,900,000	$ 29,100,000
Total debt	2,575,900,000	2,328,500,000
Less: current portion	200,000	200,000
Total long-term debt, less current portion	2,575,700,000	2,328,300,000
Senior Notes | Senior Notes, 2023
Debt Instrument [Line Items]
Senior notes	700,000,000.0	700,000,000.0
Senior Notes | Senior Notes, 2025
Debt Instrument [Line Items]
Senior notes	500,000,000.0	500,000,000.0
Senior Notes | Senior Notes, due 2027
Debt Instrument [Line Items]
Senior notes	600,000,000.0	600,000,000.0	$ 600,000,000
Other
Debt Instrument [Line Items]
Other	600,000	600,000
Revolving Credit Facility | Crestwood Midstream Revolver
Debt Instrument [Line Items]
Credit Facility	$ 801,200,000	$ 557,000,000.0

XML

Long-Term Debt (Narrative) (Detail)	1 Months Ended		6 Months Ended
	Apr. 30, 2020 USD ($)	Apr. 30, 2019 USD ($)	Jun. 30, 2020 USD ($)	Dec. 31, 2019 USD ($)	Jun. 30, 2019
Debt Instrument [Line Items]
Senior Secured Leverage Ratio, maximum			3.75
Senior Secured Leverage Ratio			1.28
Senior Notes, due 2027
Debt Instrument [Line Items]
Proceeds from Issuance of Debt	$ 591,100,000
Crestwood Midstream Revolver
Debt Instrument [Line Items]
Consolidated Leverage Ratio Maximum			5.50
Crestwood Midstream Revolver | Revolving Credit Facility
Debt Instrument [Line Items]
Available capacity			$ 424,900,000
Letters of credit outstanding			$ 23,900,000	$ 31,700,000
Debt, Weighted Average Interest Rate			2.44%	4.00%
Interest Coverage Ratio Minimum			2.50
Total Funded Debt to Consolidated Ebitda			4.16
Consolidated Ebitda To Consolidated Interest Expense			4.62
Line of Credit Facility, Increase (Decrease), Net		$ 250,000,000
Crestwood Midstream Revolver | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate			2.43%	3.96%
Crestwood Midstream Revolver | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate			4.50%	6.00%
Senior Notes | Senior Notes, due 2027
Debt Instrument [Line Items]
Senior notes		$ 600,000,000	$ 600,000,000.0	$ 600,000,000.0
Debt Instrument, Interest Rate, Stated Percentage		5.625%
Senior Notes | Senior Notes, 2025
Debt Instrument [Line Items]
Senior notes			500,000,000.0	500,000,000.0
Senior Notes | Senior Notes, 2023
Debt Instrument [Line Items]
Senior notes			$ 700,000,000.0	$ 700,000,000.0
Jackalope Gas Gathering Services, L.L.C.
Debt Instrument [Line Items]
Ownership percentage		50.00%			50.00%

XML

Earnings Per Limited Partner Unit (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net Income (Loss) Allocated to Limited Partners	$ (49.5)	$ 198.2	$ (97.8)	$ 193.3
Net Income (Loss) Allocated to Preferred Unit Holders	0.0	15.0	0.0	0.0
Net income attributable to preferred unit holders	15.0	15.0	30.0	30.0
Subordinated unitholders’ interest in net income	0.0	1.2	0.0	1.2
Net Income (Loss) Available to Common Stockholders, Diluted	$ (49.5)	$ 214.4	$ (97.8)	$ 194.5
Basic (units)	73.2	71.8	73.0	71.8
Dilutive units (units)	0.0	11.2	0.0	5.2
Weighted Average Limited Partnership Units Outstanding, Diluted	73.2	83.0	73.0	77.0
Basic (in dollars per share)	$ (0.68)	$ 2.76	$ (1.34)	$ 2.69
Diluted (in dollars per share)	$ (0.68)	$ 2.58	$ (1.34)	$ 2.53
Preferred Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	7.1	0.0	7.1	7.1
Dilutive units (units)	0.0	7.1		0.0
Niobrara Preferred Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Dilutive units (units)	0.0	3.4	0.0	4.5
Performance Shares
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	0.2	0.0	0.3	0.0
Dilutive units (units)	0.0	0.3	0.0	0.3
Subordinated Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	0.4	0.0	0.4	0.0
Dilutive units (units)	0.0	0.4	0.0	0.4
Crestwood Niobrara LLC | Preferred Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	8.2	0.0	8.2	0.0

XML

Partners' Capital (Schedule of Partners' Capital Account, Distributions) (Details) - USD ($) $ / shares in Units, $ in Millions									6 Months Ended
	May 15, 2020	May 08, 2020	Feb. 14, 2020	Feb. 07, 2020	May 15, 2019	May 08, 2019	Feb. 14, 2019	Feb. 07, 2019	Jun. 30, 2020	Jun. 30, 2019
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Date of Record		May 08, 2020		Feb. 07, 2020		May 08, 2019		Feb. 07, 2019
Distribution Made to Limited Partner, Distribution Date	May 15, 2020		Feb. 14, 2020		May 15, 2019		Feb. 14, 2019
Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit	$ 0.625		$ 0.625		$ 0.60		$ 0.60
Distribution Made to Limited Partner, Cash Distributions Paid	$ 45.7		$ 45.3		$ 43.1		$ 43.1		$ 91.0	$ 86.2

XML

Partners' Capital (Components of Net Income (Loss) Attributable to Non-Controlling Interests) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Distribution Made to Limited Partner [Line Items]
Distributions to non-controlling partner			$ 18.5	$ 6.6
Net income attributable to non-controlling partners in subsidiaries	$ (10.2)	$ (10.6)	(20.1)	(14.6)
Crestwood Midstream Partners LP
Distribution Made to Limited Partner [Line Items]
Distributions to non-controlling partner			18.5	6.6
Net income attributable to non-controlling partners in subsidiaries	$ (10.2)	$ (10.6)	(20.1)	(14.6)
Crestwood Niobrara LLC
Distribution Made to Limited Partner [Line Items]
Distributions to non-controlling partner			$ 18.5	$ 6.6

XML

Partners' Capital (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions												1 Months Ended			3 Months Ended	6 Months Ended
	Aug. 14, 2020	Aug. 07, 2020	Jul. 16, 2020	May 15, 2020	May 08, 2020	Feb. 14, 2020	Feb. 07, 2020	May 15, 2019	May 08, 2019	Feb. 14, 2019	Feb. 07, 2019	Jul. 31, 2020	Feb. 29, 2020	Apr. 30, 2019	Jun. 30, 2020	Jun. 30, 2020	Jun. 30, 2019	Apr. 09, 2019
Distribution Made to Limited Partner [Line Items]
Equity Offering Program Authorized Amount																$ 250.0
Distribution Made to Limited Partner, Distribution Date				May 15, 2020		Feb. 14, 2020		May 15, 2019		Feb. 14, 2019
Distribution Made to Limited Partner, Date of Record					May 08, 2020		Feb. 07, 2020		May 08, 2019		Feb. 07, 2019
Distributions to preferred unitholders																30.0	$ 30.0
Incentive Distribution, Distribution																91.0	86.2
Distributions to non-controlling partner																18.5	6.6
Distribution Made to Limited Partner, Cash Distributions Paid				$ 45.7		$ 45.3		$ 43.1		$ 43.1						91.0	86.2
Net proceeds from issuance of non-controlling interest																2.8	235.0
Crestwood Midstream Partners LP
Distribution Made to Limited Partner [Line Items]
Incentive Distribution, Distribution																119.0	117.5
Distributions to non-controlling partner																18.5	6.6
Distribution Made to General Partner, Cash Distributions Paid																119.0	117.5
Net proceeds from issuance of non-controlling interest																2.8	235.0
Crestwood Niobrara LLC
Distribution Made to Limited Partner [Line Items]
Distributions to non-controlling partner																$ 18.5	6.6
Net proceeds from issuance of non-controlling interest														$ 235.0
Performance Shares
Distribution Made to Limited Partner [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period													184,528			405,620
Share-based Payment Arrangement, Noncash Expense															$ 0.6	$ 0.8
Common Units
Distribution Made to Limited Partner [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period																838,556
Subsequent Event
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distribution Date	Aug. 14, 2020
Distribution Made to Limited Partner, Date of Record		Aug. 07, 2020
Distributions to preferred unitholders			$ 15.0
Subsequent Event | Crestwood Niobrara LLC
Distribution Made to Limited Partner [Line Items]
Distributions to non-controlling partner												$ 9.3
Cash Distribution | Subsequent Event
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit			$ 0.625
Crestwood LTIP
Distribution Made to Limited Partner [Line Items]
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount															$ 3.7	$ 3.7
Williams Partners LP | Crestwood Niobrara LLC
Distribution Made to Limited Partner [Line Items]
Additional voting rights acquired																		50.00%
Series A-3
Distribution Made to Limited Partner [Line Items]
Net proceeds from issuance of non-controlling interest														$ 235.0			$ 235.0
Non-Controlling Partners
Distribution Made to Limited Partner [Line Items]
Net proceeds from issuance of non-controlling interest																$ 2.8

XML

Partners' Capital Rollforward of non-controlling interest (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		6 Months Ended
	Apr. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019	Dec. 31, 2018
Increase (Decrease) in Temporary Equity [Roll Forward]
Temporary Equity, Net Income				$ 20.1	$ 10.6
Interest of non-controlling partner in subsidiary		$ 424.4		430.6	424.4	$ 426.2	$ 0.0
Non-controlling interest reclassification (Note 10)					178.8
Net proceeds from issuance of non-controlling interest				2.8	235.0
Crestwood Niobrara LLC
Increase (Decrease) in Temporary Equity [Roll Forward]
Net proceeds from issuance of non-controlling interest	$ 235.0
Non-Controlling Partners
Increase (Decrease) in Temporary Equity [Roll Forward]
Partners' Capital Account, Distributions		(3.3)	$ (3.3)
Non-controlling interest reclassification (Note 10)		$ (178.8)
Non-Controlling Partners
Increase (Decrease) in Temporary Equity [Roll Forward]
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders				(18.5)
Net proceeds from issuance of non-controlling interest				$ 2.8
Series A-3
Increase (Decrease) in Temporary Equity [Roll Forward]
Net proceeds from issuance of non-controlling interest	$ 235.0				$ 235.0

XML

Commitments and Contingencies (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Dec. 31, 2019
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Damages Sought, Value	$ 55.0
Loss Contingency Accrual, at Carrying Value	10.9	$ 10.7
Crestwood Midstream Partners LP
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Self Insurance Reserve	8.3	$ 8.3
Self Insurance Reserve Expected To Be Paid Subsequent To Next Fiscal Year	$ 5.2

XML

Commitments and Contingencies Environmental Compliance (Details) $ in Millions	1 Months Ended	6 Months Ended	12 Months Ended
	Sep. 30, 2019 bbl Release	Jun. 30, 2020 USD ($) miles	Dec. 31, 2014 bbl Release	Dec. 31, 2019 USD ($)	Sep. 15, 2015 USD ($)	May 31, 2015 bbl
Site Contingency [Line Items]
Miles of Water Gathering Pipeline Removed | miles		30
Fort Berthold Indian Reservation
Site Contingency [Line Items]
Site Contingency, Loss Exposure, Number of Releases of Produced Water | Release	2		3
Site Contingency, Loss Exposure, Release of Produced Water | bbl	5,000		28,000			5,200
Accrual for Environmental Loss Contingencies		$ 3.8		$ 6.7
Maximum
Site Contingency [Line Items]
Loss Contingency, Estimate of Possible Loss					$ 1.1
Maximum | Fort Berthold Indian Reservation
Site Contingency [Line Items]
Site Contingency, Loss Exposure in Excess of Accrual, Best Estimate		$ 8.0

XML

Commitments and Contingencies Self Insurance (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Crestwood Equity Partners LP
Other Commitments [Line Items]
Self Insurance Reserve	$ 9.4	$ 9.7
Self Insurance Reserve Expected To Be Paid Subsequent To Next Fiscal Year	6.2
Crestwood Midstream Partners LP
Other Commitments [Line Items]
Self Insurance Reserve	8.3	$ 8.3
Self Insurance Reserve Expected To Be Paid Subsequent To Next Fiscal Year	$ 5.2

XML

Commitments and Contingencies Leases (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Operating Lease, Expense	$ 7.1	$ 7.3	$ 14.6	$ 14.6
Operating lease, right-of-use assets, net	44.2		44.2		$ 53.8
Accrued expenses and other liabilities	133.8		133.8		161.7
Long-term operating lease liabilities	32.9		32.9		41.5
Property, plant and equipment	3,829.2		3,829.2		3,612.5
Less: accumulated depreciation	786.8		786.8		703.4
Property, plant and equipment, net	3,042.4		3,042.4		2,909.1
Other long-term liabilities	285.7		285.7		301.6
Finance Lease Expense	1.1	$ 1.1	2.2	$ 2.2
Operating Leases
Lessee, Lease, Description [Line Items]
Operating lease, right-of-use assets, net	44.2		44.2		53.8
Accrued expenses and other liabilities	17.8		17.8		18.1
Long-term operating lease liabilities	32.9		32.9		41.5
Operating lease, liability	50.7		50.7		59.6
Finance Lease
Lessee, Lease, Description [Line Items]
Accrued expenses and other liabilities	3.3		3.3		3.2
Property, plant and equipment	14.9		14.9		14.9
Less: accumulated depreciation	7.2		7.2		5.4
Property, plant and equipment, net	7.7		7.7		9.5
Other long-term liabilities	3.6		3.6		5.2
Finance Lease, Liability	$ 6.9		$ 6.9		$ 8.4

XML

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Related Party Transaction [Line Items]
Purchases of property, plant and equipment			$ (143.2)	$ (204.7)
Operations and maintenance expenses charged by CEQP and CMLP	$ 5.5	$ 5.9	11.7	13.4
Tres Palacios Holdings LLC
Related Party Transaction [Line Items]
Costs of product/services sold at CEQP and CMLP	0.1		0.1
Applied Consultants, Inc.
Related Party Transaction [Line Items]
Purchases of property, plant and equipment			(2.9)	(5.1)
Ascent Resources - Utica, LLC
Related Party Transaction [Line Items]
Costs of product/services sold at CEQP and CMLP	0.3	0.1	0.3	23.9
Stagecoach Gas Services LLC
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP		1.3		2.5
Costs of product/services sold at CEQP and CMLP		0.1		2.3
Crestwood Permian Basin Holdings LLC
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP	7.5		15.0
Costs of product/services sold at CEQP and CMLP	3.2	0.9	6.4	9.1
Affiliated Entity
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP	7.5	1.3	15.0	2.5
Costs of product/services sold at CEQP and CMLP	3.6	0.9	6.8	35.3
General and administrative expenses charged by CEQP to CMLP, net	10.9	10.1	18.0	21.1
Related Party Transaction, Due from (to) Related Party [Abstract]
Related party receivables	10.9		10.9		$ 7.3
Related party payables	6.9		6.9		15.6
Crestwood Equity Partners LP
Related Party Transaction [Line Items]
General and administrative expenses at CEQP charged to (from) Crestwood Holdings, net	(1.5)	(0.1)	11.3	(5.3)
Crestwood Equity Partners LP | Affiliated Entity
Related Party Transaction [Line Items]
General and administrative expenses charged by CEQP to CMLP, net	0.2	0.1	0.4	0.3
Crestwood Midstream Partners LP
Related Party Transaction [Line Items]
Purchases of property, plant and equipment			(143.2)	(204.7)
Revenues at CEQP and CMLP	0.1	0.0	0.3	0.0
Crestwood Midstream Partners LP | Affiliated Entity
Related Party Transaction [Line Items]
General and administrative expenses charged by CEQP to CMLP, net	1.0	0.9	2.1	1.8
Related Party Transaction, Due from (to) Related Party [Abstract]
Related party payables	4.5		4.5		$ 13.1
Crestwood LTIP | Crestwood Midstream Partners LP
Related Party Transaction [Line Items]
Share-based Payment Arrangement, Expense	11.9	11.0	20.1	22.9
Crestwood LTIP | Crestwood Holdings
Related Party Transaction [Line Items]
Share-based Payment Arrangement, Expense	1.7	0.2	10.9	5.6
Stagecoach Gas Services LLC
Related Party Transaction [Line Items]
Operations and maintenance expenses charged by CEQP and CMLP	1.6	1.9	3.3	3.9
Tres Palacios Holdings LLC
Related Party Transaction [Line Items]
Operations and maintenance expenses charged by CEQP and CMLP	1.1	1.0	2.2	2.2
Crestwood Permian Basin Holdings LLC
Related Party Transaction [Line Items]
Operations and maintenance expenses charged by CEQP and CMLP	$ 2.8	$ 3.0	$ 6.2	6.8
Jackalope Gas Gathering Services, L.L.C.
Related Party Transaction [Line Items]
Operations and maintenance expenses charged by CEQP and CMLP				$ 0.5

XML

Segments (Reconciliation of Net Income (Loss) to EBITDA) (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020 USD ($)	Jun. 30, 2019 USD ($)	Jun. 30, 2020 USD ($) segment	Jun. 30, 2019 USD ($)
Segment Reporting, Other Significant Reconciling Item [Line Items]
Number of Operating Segments | segment			3
Net income (loss)	$ (24.3)	$ 225.0	$ (47.7)	$ 239.1
Interest and debt expense, net	34.0	27.8	66.6	52.7
Income Tax Expense (Benefit)	(0.1)	0.3	(0.1)	0.3
Depreciation, amortization and accretion	61.0	49.3	117.1	89.1
EBITDA	70.6	302.4	135.9	381.2
Crestwood Midstream Partners LP
Segment Reporting, Other Significant Reconciling Item [Line Items]
Net income (loss)	(26.8)	222.9	(52.4)	234.5
Interest and debt expense, net	34.0	27.8	66.6	52.7
Income Tax Expense (Benefit)	(0.2)	0.3	(0.2)	0.3
Depreciation, amortization and accretion	64.6	52.7	124.2	96.1
EBITDA	$ 71.6	$ 303.7	$ 138.2	$ 383.6

XML

Segments (Summary Of Segment Information) (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020 USD ($)	Jun. 30, 2019 USD ($)	Jun. 30, 2020 USD ($) segment	Jun. 30, 2019 USD ($)	Dec. 31, 2019 USD ($)
Net income (loss)	$ (24.3)	$ 225.0	$ (47.7)	$ 239.1
Number of Operating Segments | segment			3
Depreciation, amortization and accretion	61.0	49.3	$ 117.1	89.1
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(352.7)	(683.4)	(1,080.6)	(1,518.6)
Costs of product/services sold	225.7	537.2	760.1	1,232.8
Operations and maintenance	31.6	34.7	69.2	63.3
General and administrative	29.5	22.3	44.4	59.5
Gain (loss) on long-lived assets	(3.8)	0.0	(4.8)	(2.0)
Goodwill impairment	0.0	0.0	(80.3)	0.0
Gain on acquisition	0.0	209.4	0.0	209.4
Earnings from unconsolidated affiliates, net	8.4	3.7	13.9	10.6
Other income, net	0.1	0.1	0.2	0.2
EBITDA	70.6	302.4	135.9	381.2
Goodwill	138.6		138.6		$ 218.9
Total assets	5,323.7		5,323.7		5,349.3
Marketing Supply and Logistics
Segment Reporting Information, Additional Information [Abstract]
Operating revenues				(1,123.9)
Crestwood Midstream Partners LP
Net income (loss)	(26.8)	222.9	(52.4)	234.5
Depreciation, amortization and accretion	64.6	52.7	124.2	96.1
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(352.7)	(683.4)	(1,080.6)	(1,518.6)
Costs of product/services sold	225.7	537.2	760.1	1,232.8
Operations and maintenance	31.6	34.7	69.2	63.3
General and administrative	28.4	20.9	41.9	56.9
Gain (loss) on long-lived assets	(3.8)	0.0	(4.8)	(2.0)
Goodwill impairment	0.0	0.0	(80.3)	0.0
Gain on acquisition	0.0	209.4	0.0	209.4
Earnings from unconsolidated affiliates, net	8.4	3.7	13.9	10.6
EBITDA	71.6	303.7	138.2	383.6
Goodwill	138.6		138.6		218.9
Total assets	5,472.3		5,472.3		$ 5,504.0
Intersegment Eliminations
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	16.7	28.6	59.3	85.0
Intersegment Eliminations | Gathering and Processing Operations
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(14.3)	(25.4)	(54.3)	(78.2)
Intersegment Eliminations | Storage and Transportation
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(2.4)	(3.2)	(5.0)	(6.8)
Intersegment Eliminations | Marketing Supply and Logistics
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	16.7	28.6	59.3	85.0
Intersegment Eliminations | Crestwood Midstream Partners LP | Gathering and Processing Operations
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(14.3)	(25.4)	(54.3)	(78.2)
Intersegment Eliminations | Crestwood Midstream Partners LP | Storage and Transportation
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(2.4)	(3.2)	(5.0)	(6.8)
Intersegment Eliminations | Crestwood Midstream Partners LP | Marketing Supply and Logistics
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	16.7	28.6	59.3	85.0
Corporate and Eliminations [Member]
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	0.0	0.0	0.0	0.0
Corporate and Eliminations [Member] | Crestwood Midstream Partners LP
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	0.0	0.0	0.0	0.0
Operating Segments | Gathering and Processing Operations
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(114.5)	(199.7)	(329.4)	(382.0)
Costs of product/services sold	21.3	108.9	129.6	246.9
Operations and maintenance	19.3	24.6	46.3	42.7
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	(3.6)	(0.2)	(4.6)	(2.0)
Goodwill impairment			(80.3)
Gain on acquisition		209.4		209.4
Earnings from unconsolidated affiliates, net	(1.0)	(2.8)	(0.2)	(3.0)
Other income, net	0.0	0.0	0.0	0.0
EBITDA	83.6	298.0	122.7	375.0
Goodwill	45.9		45.9
Total assets	3,589.8		3,589.8
Operating Segments | Storage and Transportation
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(3.1)	(4.9)	(6.6)	(12.7)
Costs of product/services sold	0.1	0.0	0.3	0.0
Operations and maintenance	0.7	0.9	2.1	1.9
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	0.0	0.0	0.0	0.0
Goodwill impairment			0.0
Gain on acquisition		0.0		0.0
Earnings from unconsolidated affiliates, net	9.4	6.5	14.1	13.6
Other income, net	0.0	0.0	0.0	0.0
EBITDA	14.1	13.7	23.3	31.2
Goodwill	0.0		0.0
Total assets	964.7		964.7
Operating Segments | Marketing Supply and Logistics
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(235.1)	(478.8)	(744.6)	(1,123.9)
Costs of product/services sold	204.3	428.3	630.2	985.9
Operations and maintenance	11.6	9.2	20.8	18.7
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	(0.2)	0.0	(0.2)	(0.2)
Goodwill impairment			0.0
Gain on acquisition		0.0		0.0
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
Other income, net	0.0	0.0	0.0	0.0
EBITDA	2.3	12.7	34.1	34.1
Goodwill	92.7		92.7
Total assets	736.9		736.9
Operating Segments | Crestwood Midstream Partners LP | Gathering and Processing Operations
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(114.5)	(199.7)	(329.4)	(382.0)
Costs of product/services sold	21.3	108.9	129.6	246.9
Operations and maintenance	19.3	24.6	46.3	42.7
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	(3.6)	(0.2)	(4.6)	(2.0)
Goodwill impairment			(80.3)
Gain on acquisition		209.4		209.4
Earnings from unconsolidated affiliates, net	(1.0)	(2.8)	(0.2)	(3.0)
EBITDA	83.6	298.0	122.7	375.0
Goodwill	45.9		45.9
Total assets	3,742.1		3,742.1
Operating Segments | Crestwood Midstream Partners LP | Storage and Transportation
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(3.1)	(4.9)	(6.6)	(12.7)
Costs of product/services sold	0.1	0.0	0.3	0.0
Operations and maintenance	0.7	0.9	2.1	1.9
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	0.0	0.0	0.0	0.0
Goodwill impairment			0.0
Gain on acquisition		0.0		0.0
Earnings from unconsolidated affiliates, net	9.4	6.5	14.1	13.6
EBITDA	14.1	13.7	23.3	31.2
Goodwill	0.0		0.0
Total assets	964.7		964.7
Operating Segments | Crestwood Midstream Partners LP | Marketing Supply and Logistics
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(235.1)	(478.8)	(744.6)	(1,123.9)
Costs of product/services sold	204.3	428.3	630.2	985.9
Operations and maintenance	11.6	9.2	20.8	18.7
General and administrative	0.0	0.0	0.0	0.0
Gain (loss) on long-lived assets	(0.2)	0.0	(0.2)	(0.2)
Goodwill impairment			0.0
Gain on acquisition		0.0		0.0
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
EBITDA	2.3	12.7	34.1	34.1
Goodwill	92.7		92.7
Total assets	736.9		736.9
Corporate, Non-Segment
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	0.0	0.0	0.0	0.0
Costs of product/services sold	0.0	0.0	0.0	0.0
Operations and maintenance	0.0	0.0	0.0	0.0
General and administrative	29.5	22.3	44.4	59.5
Gain (loss) on long-lived assets	0.0	0.2	0.0	0.2
Goodwill impairment			0.0
Gain on acquisition		0.0		0.0
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
Other income, net	0.1	0.1	0.2	0.2
EBITDA	(29.4)	(22.0)	(44.2)	(59.1)
Goodwill	0.0		0.0
Total assets	32.3		32.3
Corporate, Non-Segment | Crestwood Midstream Partners LP
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	0.0	0.0	0.0	0.0
Costs of product/services sold	0.0	0.0	0.0	0.0
Operations and maintenance	0.0	0.0	0.0	0.0
General and administrative	28.4	20.9	41.9	56.9
Gain (loss) on long-lived assets	0.0	0.2	0.0	0.2
Goodwill impairment			0.0
Gain on acquisition		0.0		0.0
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
EBITDA	(28.4)	$ (20.7)	(41.9)	$ (56.7)
Goodwill	0.0		0.0
Total assets	$ 28.6		$ 28.6

XML

Segments (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Segment Reporting Information [Line Items]
Interest, taxes, depreciation and amortization included in earnings from equity method investments	$ 9.5	$ 10.3	$ 23.3	$ 23.0

XML

Revenue Recognition Narrative (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Revenue Recognition [Abstract]
ASC 606 accounts receivable	$ 158.3	$ 225.0

XML

Revenue Recognition Contract Assets and Liabilities (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2020	Dec. 31, 2019
Business Acquisition [Line Items]
Contract Assets (Non-current)	$ 1.2	$ 1.2	$ 1.2
Contract Liabilities (Current)	10.2	10.2	8.8
Contract Liabilities (Non-current)	159.6	159.6	$ 144.7
Contract with Customer, Liability, Revenue Recognized	$ 3.1	$ 6.9

XML

Revenue Recognition Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Disaggregation of Revenue [Line Items]
Revenues	$ 352.7	$ 683.4	$ 1,080.6	$ 1,518.6
Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue including intersegment eliminations	128.8	225.1	383.7	460.2
Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue including intersegment eliminations	5.5	8.1	11.6	19.5
Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenues				1,123.9
Revenue including intersegment eliminations	235.1	478.8	744.6
Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	33.2	42.9	77.0	73.1
Natural Gas Gathering | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	33.2	42.9	77.0	73.1
Natural Gas Gathering | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Natural Gas Gathering | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	17.9	15.1	44.4	30.4
Crude Oil Gathering | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	17.9	15.1	44.4	30.4
Crude Oil Gathering | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Crude Oil Gathering | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Water Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	18.3	19.0	41.3	35.8
Water Gathering | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	18.3	19.0	41.3	35.8
Water Gathering | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Water Gathering | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Natural Gas Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	7.1	8.1	17.3	10.6
Natural Gas Processing | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	7.1	8.1	17.3	10.6
Natural Gas Processing | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Natural Gas Processing | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Natural Gas Compression
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5.7	6.2	12.0	12.2
Natural Gas Compression | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5.7	6.2	12.0	12.2
Natural Gas Compression | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Natural Gas Compression | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Crude Oil Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.7	1.5	1.4	2.7
Crude Oil Storage | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.4	0.5	0.9	1.0
Crude Oil Storage | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.1	1.5	1.7	2.9
Crude Oil Storage | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
NGL Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3.6	1.3	5.2	2.6
NGL Storage | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
NGL Storage | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
NGL Storage | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3.6	1.3	5.2	2.6
Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.9	1.0	2.0	2.0
Crude Oil Pipeline | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Crude Oil Pipeline | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.3	1.5	2.9	3.2
Crude Oil Pipeline | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
NGL Pipeline
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.2		0.2
NGL Pipeline | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0		0.0
NGL Pipeline | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0		0.0
NGL Pipeline | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.2		0.2
Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.8	3.3	5.4	6.3
Crude Oil Transportation | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.5	1.8	3.5	3.3
Crude Oil Transportation | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Crude Oil Transportation | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.3	1.5	1.9	3.0
NGL Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2.6	2.1	4.3	6.2
NGL Transportation | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
NGL Transportation | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
NGL Transportation | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2.6	2.1	4.3	6.2
Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.7	2.5	3.7	8.3
Crude Oil Rail Loading | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Crude Oil Rail Loading | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2.9	3.9	6.3	11.1
Crude Oil Rail Loading | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	15.6	14.0	34.2	48.5
Natural Gas Product Sales | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	6.9	10.9	18.9	29.7
Natural Gas Product Sales | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Natural Gas Product Sales | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	15.5	7.9	33.8	30.2
Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	129.7	385.6	484.7	764.0
Crude Oil Product Sales | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	34.8	110.2	155.9	241.8
Crude Oil Product Sales | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Crude Oil Product Sales | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	102.0	291.4	352.2	581.5
NGL Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	95.1	139.8	253.0	370.4
NGL Product Sales | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3.0	10.4	12.5	22.3
NGL Product Sales | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
NGL Product Sales | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	92.4	133.9	252.7	355.4
Other revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.3	0.6	0.9	0.8
Other revenue | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Other revenue | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.2	1.2	0.7	2.3
Other revenue | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.2	0.3	0.7	0.3
Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenues	(16.7)	(28.6)	(59.3)	(85.0)
Intersegment Eliminations | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenues	14.3	25.4	54.3	78.2
Intersegment Eliminations | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues	2.4	3.2	5.0	6.8
Intersegment Eliminations | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenues	(16.7)	(28.6)	(59.3)	(85.0)
Intersegment Eliminations | Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Water Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Natural Gas Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Natural Gas Compression
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Crude Oil Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(0.8)	(0.5)	(1.2)	(1.2)
Intersegment Eliminations | NGL Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(0.4)	(0.5)	(0.9)	(1.2)
Intersegment Eliminations | NGL Pipeline
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0		0.0
Intersegment Eliminations | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | NGL Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.0	0.0	0.0	0.0
Intersegment Eliminations | Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(1.2)	(1.4)	(2.6)	(2.8)
Intersegment Eliminations | Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(6.8)	(4.8)	(18.5)	(11.4)
Intersegment Eliminations | Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(7.1)	(16.0)	(23.4)	(59.3)
Intersegment Eliminations | NGL Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(0.3)	(4.5)	(12.2)	(7.3)
Intersegment Eliminations | Other revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(0.1)	(0.9)	(0.5)	(1.8)
Revenue from Contract with Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	334.4	643.0	987.0	1,373.9
Revenue from Contract with Customer | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	128.8	225.1	383.7	460.2
Revenue from Contract with Customer | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5.5	8.1	11.6	19.5
Revenue from Contract with Customer | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	216.8	438.4	651.0	979.2
Revenue from Contract with Customer | Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(16.7)	(28.6)	(59.3)	(85.0)
Product and Service, Other
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	18.3	40.4	93.6	144.7
Product and Service, Other | Gathering and Processing Operations
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	0.0	0.0	0.0	0.0
Product and Service, Other | Storage and Transportation
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	0.0	0.0	0.0	0.0
Product and Service, Other | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	18.3	40.4	93.6	144.7
Product and Service, Other | Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Non-Topic 606 revenues	$ 0.0	$ 0.0	$ 0.0	$ 0.0

XML

Revenue Recognition Remaining Performance Obligations (Details) $ in Millions	Jun. 30, 2020 USD ($)
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	$ 220.9
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-04-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	$ 52.3
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	$ 94.1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	$ 63.2
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	$ 8.0
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	$ 3.3
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	17 years

XML

Condensed Consolidating Financial Information (Balance Sheet) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019	Jun. 30, 2019	Dec. 31, 2018
Current assets:
Cash	$ 6.7	$ 25.7
Accounts receivable	165.9	242.2
Inventory	88.9	53.7
Total current assets	314.6	376.4
Property, plant and equipment, net	3,042.4	2,909.1
Operating lease, right-of-use assets, net	44.2	53.8
Investment	961.9	980.4
Other non-current assets	4.9	5.5
Total assets	5,323.7	5,349.3
Current liabilities:
Accounts payable	118.6	189.2
Total current liabilities	284.8	357.8
Long-term liabilities:
Long-term debt, less current portion	2,575.7	2,328.3
Other long-term liabilities	285.7	301.6
Deferred income taxes	2.3	2.6
Total liabilities	3,148.5	2,990.3
Interest of non-controlling partner in subsidiary	430.6	426.2	$ 424.4	$ 0.0
Total partners’ capital	1,744.6	1,932.8
Total liabilities and capital	5,323.7	5,349.3
Eliminations
Current assets:
Cash	0.0	0.0
Accounts receivable	0.0	0.0
Inventory	0.0	0.0
Other	0.0	0.0
Total current assets	0.0	0.0
Property, plant and equipment, net	0.0	0.0
Operating lease, right-of-use assets, net	0.0	0.0
Goodwill and intangible assets, net	0.0	0.0
Investment in consolidated affiliates	(4,501.0)	(4,451.6)
Investment	0.0	0.0
Other non-current assets	0.0	0.0
Total assets	(4,501.0)	(4,451.6)
Current liabilities:
Accounts payable	0.0	0.0
Other current liabilities	0.0	0.0
Total current liabilities	0.0	0.0
Long-term liabilities:
Long-term debt, less current portion	0.0	0.0
Other long-term liabilities	0.0	0.0
Deferred income taxes	0.0	0.0
Total liabilities	0.0	0.0
Interest of non-controlling partner in subsidiary (Note 10)		0.0
Interest of non-controlling partner in subsidiary	0.0
Partners' capital	(4,501.0)	(4,451.6)
Total liabilities and capital	(4,501.0)	(4,451.6)
Parent Company, Crestwood Midstream Partners, LP | Reportable Legal Entities
Current assets:
Cash	0.4	1.8
Accounts receivable	0.0	0.0
Inventory	0.0	0.0
Other	0.0	0.0
Total current assets	0.4	1.8
Property, plant and equipment, net	0.0	0.0
Operating lease, right-of-use assets, net	0.0	0.0
Goodwill and intangible assets, net	0.0	0.0
Investment in consolidated affiliates	4,501.0	4,451.6
Investment	0.0	0.0
Other non-current assets	0.0	0.0
Total assets	4,501.4	4,453.4
Current liabilities:
Accounts payable	0.0	0.0
Other current liabilities	25.2	25.8
Total current liabilities	25.2	25.8
Long-term liabilities:
Long-term debt, less current portion	2,575.7	2,328.3
Other long-term liabilities	0.0	0.0
Deferred income taxes	0.0	0.0
Total liabilities	2,600.9	2,354.1
Interest of non-controlling partner in subsidiary (Note 10)		0.0
Interest of non-controlling partner in subsidiary	0.0
Partners' capital	1,900.5	2,099.3
Total liabilities and capital	4,501.4	4,453.4
Guarantor Subsidiaries | Reportable Legal Entities
Current assets:
Cash	0.0	0.0
Accounts receivable	146.5	229.1
Inventory	88.9	53.7
Other	52.8	54.6
Total current assets	288.2	337.4
Property, plant and equipment, net	2,410.1	2,331.3
Operating lease, right-of-use assets, net	41.5	51.0
Goodwill and intangible assets, net	671.2	650.7
Investment in consolidated affiliates	0.0	0.0
Investment	0.0	0.0
Other non-current assets	2.4	1.9
Total assets	3,413.4	3,372.3
Current liabilities:
Accounts payable	114.6	175.9
Other current liabilities	114.8	123.9
Total current liabilities	229.4	299.8
Long-term liabilities:
Long-term debt, less current portion	0.0	0.0
Other long-term liabilities	165.8	174.8
Deferred income taxes	0.6	0.7
Total liabilities	395.8	475.3
Interest of non-controlling partner in subsidiary (Note 10)		0.0
Interest of non-controlling partner in subsidiary	0.0
Partners' capital	3,017.6	2,897.0
Total liabilities and capital	3,413.4	3,372.3
Non-Guarantor Subsidiaries | Reportable Legal Entities
Current assets:
Cash	5.7	23.6
Accounts receivable	19.3	12.8
Inventory	0.0	0.0
Other	0.3	0.2
Total current assets	25.3	36.6
Property, plant and equipment, net	783.6	736.2
Operating lease, right-of-use assets, net	2.7	2.8
Goodwill and intangible assets, net	284.5	373.4
Investment in consolidated affiliates	0.0	0.0
Investment	961.9	980.4
Other non-current assets	0.5	0.5
Total assets	2,058.5	2,129.9
Current liabilities:
Accounts payable	1.5	10.7
Other current liabilities	24.8	17.6
Total current liabilities	26.3	28.3
Long-term liabilities:
Long-term debt, less current portion	0.0	0.0
Other long-term liabilities	118.2	120.8
Deferred income taxes	0.0	0.0
Total liabilities	144.5	149.1
Interest of non-controlling partner in subsidiary (Note 10)		426.2
Interest of non-controlling partner in subsidiary	430.6
Partners' capital	1,483.4	1,554.6
Total liabilities and capital	2,058.5	2,129.9
Crestwood Midstream Partners LP
Current assets:
Cash	6.1	25.4
Accounts receivable	165.8	241.9
Inventory	88.9	53.7
Other	53.1	54.8
Total current assets	313.9	375.8
Property, plant and equipment, net	3,193.7	3,067.5
Operating lease, right-of-use assets, net	44.2	53.8
Goodwill and intangible assets, net	955.7	1,024.1
Investment in consolidated affiliates	0.0	0.0
Investment	961.9	980.4
Other non-current assets	2.9	2.4
Total assets	5,472.3	5,504.0
Current liabilities:
Accounts payable	116.1	186.6
Other current liabilities	164.8	167.3
Total current liabilities	280.9	353.9
Long-term liabilities:
Long-term debt, less current portion	2,575.7	2,328.3
Other long-term liabilities	284.0	295.6
Deferred income taxes	0.6	0.7
Total liabilities	3,141.2	2,978.5
Interest of non-controlling partner in subsidiary (Note 10)		426.2
Interest of non-controlling partner in subsidiary	430.6
Partners' capital	1,900.5	2,099.3
Total liabilities and capital	$ 5,472.3	$ 5,504.0

XML

Condensed Consolidating Financial Information (Statements Of Operations) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Income Tax Expense (Benefit)	$ (0.1)	$ 0.3	$ (0.1)	$ 0.3
Revenues	352.7	683.4	1,080.6	1,518.6
Costs of product/services sold	225.7	537.2	760.1	1,232.8
Operating expenses and other:
Operations and maintenance	31.6	34.7	69.2	63.3
General and administrative	29.5	22.3	44.4	59.5
Depreciation, amortization and accretion	61.0	49.3	117.1	89.1
Loss on long-lived assets, net	3.8	0.0	4.8	2.0
Gain on acquisition	0.0	(209.4)	0.0	(209.4)
Goodwill impairment	0.0	0.0	80.3	0.0
Total expenses	125.9	(103.1)	315.8	4.5
Operating income (loss)	1.1	249.3	4.7	281.3
Earnings from unconsolidated affiliates, net	8.4	3.7	13.9	10.6
Interest and debt expense, net	(34.0)	(27.8)	(66.6)	(52.7)
Income (loss) before income taxes	(24.4)	225.3	(47.8)	239.4
Net income (loss)	(24.3)	225.0	(47.7)	239.1
Net income attributable to non-controlling partner in subsidiary	10.2	10.6	20.1	14.6
Net income (loss) attributable to parent	(34.5)	214.4	(67.8)	224.5
Eliminations
Income Tax Expense (Benefit)	0.0	0.0	0.0	0.0
Revenues	0.0	0.0	0.0	0.0
Costs of product/services sold	0.0	0.0	0.0	0.0
Operating expenses and other:
Operations and maintenance	0.0	0.0	0.0	0.0
General and administrative	0.0	0.0	0.0	0.0
Depreciation, amortization and accretion	0.0	0.0	0.0	0.0
Loss on long-lived assets, net	0.0		0.0	0.0
Gain on acquisition		0.0		0.0
Goodwill impairment			0.0
Total expenses	0.0	0.0	0.0	0.0
Operating income (loss)	0.0	0.0	0.0	0.0
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
Interest and debt expense, net	0.0	0.0	0.0	0.0
Loss from unconsolidated affiliates	(11.7)	(250.0)	(26.5)	(301.0)
Income (loss) before income taxes	(11.7)	(250.0)	(26.5)	(301.0)
Net income (loss)	(11.7)	(250.0)	(26.5)	(301.0)
Net income attributable to non-controlling partner in subsidiary	0.0	0.0	0.0	0.0
Net income (loss) attributable to parent	(11.7)	(250.0)	(26.5)	(301.0)
Non-Guarantor Subsidiaries | Reportable Legal Entities
Income Tax Expense (Benefit)	0.0	0.0	0.0	0.0
Revenues	16.2	20.2	43.7	20.2
Costs of product/services sold	0.2	0.0	0.2	0.0
Operating expenses and other:
Operations and maintenance	5.1	7.2	10.9	7.2
General and administrative	0.0	0.0	0.0	0.0
Depreciation, amortization and accretion	14.3	9.7	26.1	9.7
Loss on long-lived assets, net	1.8		1.8	0.0
Gain on acquisition		209.4		209.4
Goodwill impairment			80.3
Total expenses	21.2	(192.5)	119.1	(192.5)
Operating income (loss)	(5.2)	212.7	(75.6)	212.7
Earnings from unconsolidated affiliates, net	8.4	3.7	13.9	10.6
Interest and debt expense, net	0.0	0.0	0.0	0.0
Loss from unconsolidated affiliates	0.0	0.0	0.0	0.0
Income (loss) before income taxes	3.2	216.4	(61.7)	223.3
Net income (loss)	3.2	216.4	(61.7)	223.3
Net income attributable to non-controlling partner in subsidiary	10.2	10.6	20.1	14.6
Net income (loss) attributable to parent	(7.0)	205.8	(81.8)	208.7
Crestwood Midstream Partners LP
Income Tax Expense (Benefit)	(0.2)	0.3	(0.2)	0.3
Revenues	352.7	683.4	1,080.6	1,518.6
Costs of product/services sold	225.7	537.2	760.1	1,232.8
Operating expenses and other:
Operations and maintenance	31.6	34.7	69.2	63.3
General and administrative	28.4	20.9	41.9	56.9
Depreciation, amortization and accretion	64.6	52.7	124.2	96.1
Loss on long-lived assets, net	3.8		4.8	2.0
Gain on acquisition		209.4		209.4
Goodwill impairment			80.3
Total expenses	128.4	(101.1)	320.4	8.9
Operating income (loss)	(1.4)	247.3	0.1	276.9
Earnings from unconsolidated affiliates, net	8.4	3.7	13.9	10.6
Interest and debt expense, net	(34.0)	(27.8)	(66.6)	(52.7)
Loss from unconsolidated affiliates	0.0	0.0	0.0	0.0
Income (loss) before income taxes	(27.0)	223.2	(52.6)	234.8
Net income (loss)	(26.8)	222.9	(52.4)	234.5
Net income attributable to non-controlling partner in subsidiary	10.2	10.6	20.1	14.6
Net income (loss) attributable to parent	(37.0)	212.3	(72.5)	219.9
Guarantor Subsidiaries | Reportable Legal Entities
Income Tax Expense (Benefit)	(0.2)	0.3	(0.2)	0.3
Revenues	336.5	663.2	1,036.9	1,498.4
Costs of product/services sold	225.5	537.2	759.9	1,232.8
Operating expenses and other:
Operations and maintenance	26.5	27.5	58.3	56.1
General and administrative	13.6	11.2	9.2	28.5
Depreciation, amortization and accretion	50.3	43.0	98.1	86.4
Loss on long-lived assets, net	2.0		3.0	2.0
Gain on acquisition		0.0		0.0
Goodwill impairment			0.0
Total expenses	92.4	81.7	168.6	173.0
Operating income (loss)	18.6	44.3	108.4	92.6
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
Interest and debt expense, net	(0.1)	0.2	(0.3)	0.0
Loss from unconsolidated affiliates	0.0	0.0	0.0	0.0
Income (loss) before income taxes	18.5	44.5	108.1	92.6
Net income (loss)	18.7	44.2	108.3	92.3
Net income attributable to non-controlling partner in subsidiary	0.0	0.0	0.0	0.0
Net income (loss) attributable to parent	18.7	44.2	108.3	92.3
Parent Company, Crestwood Midstream Partners, LP | Reportable Legal Entities
Income Tax Expense (Benefit)	0.0	0.0	0.0	0.0
Revenues	0.0	0.0	0.0	0.0
Costs of product/services sold	0.0	0.0	0.0	0.0
Operating expenses and other:
Operations and maintenance	0.0	0.0	0.0	0.0
General and administrative	14.8	9.7	32.7	28.4
Depreciation, amortization and accretion	0.0	0.0	0.0	0.0
Loss on long-lived assets, net	0.0		0.0	0.0
Gain on acquisition		0.0		0.0
Goodwill impairment			0.0
Total expenses	14.8	9.7	32.7	28.4
Operating income (loss)	(14.8)	(9.7)	(32.7)	(28.4)
Earnings from unconsolidated affiliates, net	0.0	0.0	0.0	0.0
Interest and debt expense, net	(33.9)	(28.0)	(66.3)	(52.7)
Loss from unconsolidated affiliates	11.7	250.0	26.5	301.0
Income (loss) before income taxes	(37.0)	212.3	(72.5)	219.9
Net income (loss)	(37.0)	212.3	(72.5)	219.9
Net income attributable to non-controlling partner in subsidiary	0.0	0.0	0.0	0.0
Net income (loss) attributable to parent	$ (37.0)	$ 212.3	$ (72.5)	$ 219.9

XML

Condensed Consolidating Financial Information (Statements Of Cash Flows) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Cash flows from operating activities	$ 183.4	$ 193.9
Cash flows from investing activities:
Acquisition, net of cash acquired	162.3	462.1
Purchases of property, plant and equipment	(143.2)	(204.7)
Investments in unconsolidated affiliates	(6.0)	(40.9)
Capital distributions from unconsolidated affiliates	18.9	24.2
Other	(0.3)	(0.5)
Net cash used in investing activities	(292.9)	(684.0)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	742.5	1,544.0
Payments on long-term debt	(498.2)	(1,159.5)
Payments on finance leases	(1.6)	(1.9)
Payments for debt-related deferred costs	0.0	(9.0)
Net proceeds from issuance of non-controlling interest	2.8	235.0
Distributions to partners	(91.0)	(86.2)
Taxes paid for unit-based compensation vesting	(15.5)	(10.6)
Net cash provided by financing activities	90.5	475.0
Net change in cash	(19.0)	(15.1)
Cash at beginning of period	25.7	17.2
Cash at end of period	6.7	2.1
Eliminations
Cash flows from operating activities	0.0	0.0
Cash flows from investing activities:
Acquisition, net of cash acquired	0.0	0.0
Purchases of property, plant and equipment	0.0	0.0
Investments in unconsolidated affiliates	0.0	0.0
Capital distributions from unconsolidated affiliates	0.0	0.0
Capital distributions from consolidated affiliates	(8.2)	217.1
Other	0.0	0.0
Net cash used in investing activities	(8.2)	217.1
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	0.0	0.0
Payments on long-term debt	0.0	0.0
Payments on finance leases	0.0	0.0
Payments for debt-related deferred costs		0.0
Net proceeds from issuance of non-controlling interest	0.0	0.0
Distributions to partners	0.0	0.0
Contributions from (distributions to) parent	8.2	(217.1)
Taxes paid for unit-based compensation vesting	0.0	0.0
Change in intercompany balances	0.0	0.0
Net cash provided by financing activities	8.2	(217.1)
Net change in cash	0.0	0.0
Cash at beginning of period	0.0	0.0
Cash at end of period	0.0	0.0
Non-Guarantor Subsidiaries | Reportable Legal Entities
Cash flows from operating activities	80.1	(27.3)
Cash flows from investing activities:
Acquisition, net of cash acquired	0.0	462.1
Purchases of property, plant and equipment	(87.0)	(77.0)
Investments in unconsolidated affiliates	(6.0)	(40.9)
Capital distributions from unconsolidated affiliates	18.9	24.2
Capital distributions from consolidated affiliates	0.0	0.0
Other	0.0	0.0
Net cash used in investing activities	(74.1)	(555.8)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	0.0	0.0
Payments on long-term debt	0.0	0.0
Payments on finance leases	0.0	0.0
Payments for debt-related deferred costs		0.0
Net proceeds from issuance of non-controlling interest	2.8	235.0
Distributions to partners	(18.5)	(6.6)
Contributions from (distributions to) parent	(8.2)	217.1
Taxes paid for unit-based compensation vesting	0.0	0.0
Change in intercompany balances	0.0	137.7
Net cash provided by financing activities	(23.9)	583.2
Net change in cash	(17.9)	0.1
Cash at beginning of period	23.6	0.0
Cash at end of period	5.7	0.1
Parent Company, Crestwood Midstream Partners, LP | Reportable Legal Entities
Cash flows from operating activities	(96.4)	(87.1)
Cash flows from investing activities:
Acquisition, net of cash acquired	0.0	0.0
Purchases of property, plant and equipment	0.0	0.0
Investments in unconsolidated affiliates	0.0	0.0
Capital distributions from unconsolidated affiliates	0.0	0.0
Capital distributions from consolidated affiliates	8.2	(217.1)
Other	0.0	0.0
Net cash used in investing activities	8.2	(217.1)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	742.5	1,544.0
Payments on long-term debt	(498.2)	(1,159.1)
Payments on finance leases	0.0	0.0
Payments for debt-related deferred costs		(9.0)
Net proceeds from issuance of non-controlling interest	0.0	0.0
Distributions to partners	(119.0)	(117.5)
Contributions from (distributions to) parent	0.0	0.0
Taxes paid for unit-based compensation vesting	0.0	0.0
Change in intercompany balances	(38.5)	30.7
Net cash provided by financing activities	86.8	289.1
Net change in cash	(1.4)	(15.1)
Cash at beginning of period	1.8	16.5
Cash at end of period	0.4	1.4
Crestwood Midstream Partners LP
Cash flows from operating activities	181.1	195.1
Cash flows from investing activities:
Acquisition, net of cash acquired	162.3	462.1
Purchases of property, plant and equipment	(143.2)	(204.7)
Investments in unconsolidated affiliates	(6.0)	(40.9)
Capital distributions from unconsolidated affiliates	18.9	24.2
Capital distributions from consolidated affiliates	0.0	0.0
Other	(0.3)	(0.5)
Net cash used in investing activities	(292.9)	(684.0)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	742.5	1,544.0
Payments on long-term debt	(498.2)	(1,159.5)
Payments on finance leases	(1.6)	(1.9)
Payments for debt-related deferred costs		(9.0)
Net proceeds from issuance of non-controlling interest	2.8	235.0
Distributions to partners	(137.5)	(124.1)
Contributions from (distributions to) parent	0.0	0.0
Taxes paid for unit-based compensation vesting	(15.5)	(10.6)
Change in intercompany balances	0.0	0.0
Net cash provided by financing activities	92.5	473.9
Net change in cash	(19.3)	(15.0)
Cash at beginning of period	25.4	16.5
Cash at end of period	6.1	1.5
Guarantor Subsidiaries | Reportable Legal Entities
Cash flows from operating activities	197.4	309.5
Cash flows from investing activities:
Acquisition, net of cash acquired	162.3	0.0
Purchases of property, plant and equipment	(56.2)	(127.7)
Investments in unconsolidated affiliates	0.0	0.0
Capital distributions from unconsolidated affiliates	0.0	0.0
Capital distributions from consolidated affiliates	0.0	0.0
Other	(0.3)	(0.5)
Net cash used in investing activities	(218.8)	(128.2)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	0.0	0.0
Payments on long-term debt	0.0	(0.4)
Payments on finance leases	(1.6)	(1.9)
Payments for debt-related deferred costs		0.0
Net proceeds from issuance of non-controlling interest	0.0	0.0
Distributions to partners	0.0	0.0
Contributions from (distributions to) parent	0.0	0.0
Taxes paid for unit-based compensation vesting	(15.5)	(10.6)
Change in intercompany balances	38.5	(168.4)
Net cash provided by financing activities	21.4	(181.3)
Net change in cash	0.0	0.0
Cash at beginning of period	0.0	0.0
Cash at end of period	$ 0.0	$ 0.0