Crestwood Equity Partners (CEQP) 10-K 22 Feb 19 2018 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2018	Feb. 11, 2019	Jun. 29, 2018
Entity Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	FY
Trading Symbol	CEQP
Entity Registrant Name	Crestwood Equity Partners LP
Entity Central Index Key	1,136,352
Current Fiscal Year End Date	--12-31
Entity Shell Company	false
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		71,901,462
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 1.6
CMLP
Entity Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	FY
Entity Registrant Name	Crestwood Midstream Partners LP
Entity Central Index Key	1,304,464
Current Fiscal Year End Date	--12-31
Entity Shell Company	false
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		0
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 0

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Assets
Cash	$ 0.9	$ 1.3
Restricted cash	16.3	0
Accounts receivable, less allowance for doubtful accounts	251.5	442.7
Inventory	64.6	68.4
Assets from price risk management activities	34.7	7.2
Prepaid expenses and other current assets	11.3	10.9
Total current assets	379.3	530.5
Property, plant and equipment	2,598.1	2,285.2
Less: accumulated depreciation and depletion	568.4	464.4
Property, plant and equipment, net	2,029.7	1,820.8
Intangible assets	770.3	788.8
Less: accumulated amortization	216.5	191.6
Intangible assets, net	553.8	597.2
Goodwill	138.6	147.6
Investments in unconsolidated affiliates	1,188.2	1,183
Other non-current assets	4.9	5.8
Total assets	4,294.5	4,284.9
Current liabilities:
Accounts payable	213	349.4
Accrued expenses and other liabilities	112.4	105.9
Liabilities from price risk management activities	5.8	48.9
Current portion of long-term debt	0.9	0.9
Total current liabilities	332.1	505.1
Long-term debt, less current portion	1,752.4	1,491.3
Other long-term liabilities	173.6	104.7
Deferred income taxes	2.6	3.3
Commitments and contingencies (Note 15)
Partners’ capital:
Partners' capital	1,240.5	1,393.5
Preferred units	612	612
Total CEQP/CMLP partners’ capital	1,852.5	2,005.5
Interest of non-controlling partner in subsidiary	181.3	175
Total partners’ capital	2,033.8	2,180.5
Total liabilities and partners’ capital	4,294.5	4,284.9
CMLP
Assets
Cash	0.2	1
Restricted cash	16.3	0
Accounts receivable, less allowance for doubtful accounts	249.9	442.6
Inventory	64.6	68.4
Assets from price risk management activities	34.7	7.2
Prepaid expenses and other current assets	11.3	10.9
Total current assets	377	530.1
Property, plant and equipment	2,928.2	2,615.3
Less: accumulated depreciation and depletion	725.9	607.8
Property, plant and equipment, net	2,202.3	2,007.5
Intangible assets	770.3	773.3
Less: accumulated amortization	216.5	177.6
Intangible assets, net	553.8	595.7
Goodwill	138.6	147.6
Investments in unconsolidated affiliates	1,188.2	1,183
Other non-current assets	2.1	2.4
Total assets	4,462	4,466.3
Current liabilities:
Accounts payable	210.5	346.8
Accrued expenses and other liabilities	111.3	104.7
Liabilities from price risk management activities	5.8	48.9
Current portion of long-term debt	0.9	0.9
Total current liabilities	328.5	501.3
Long-term debt, less current portion	1,752.4	1,491.3
Other long-term liabilities	171	102.6
Deferred income taxes	0.6	0.7
Partners’ capital:
Total CEQP/CMLP partners’ capital	2,028.2	2,195.4
Interest of non-controlling partner in subsidiary	181.3	175
Total partners’ capital	2,209.5	2,370.4
Total liabilities and partners’ capital	$ 4,462	$ 4,466.3

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Allowance for doubtful accounts	$ 0.3	$ 2.4
Limited partners' units, issued	71,659,385	70,721,563
Limited partners' units, outstanding	71,659,385	70,721,563
Preferred units, issued	71,257,445	71,257,445
Preferred units, outstanding	71,257,445	71,257,445
CMLP
Allowance for doubtful accounts	$ 0.3	$ 2.4

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenues:
Revenues	$ 3,654.1	$ 3,880.9	$ 2,520.5
Related party (Note 16)	1	1.8	2.6
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 16)	134.7	15.3	17.7
Total costs of products/services sold	3,129.4	3,374.7	1,925.1
Operating expenses and other:
Operations and maintenance	125.8	136	158.1
General and administrative	88.1	96.5	88.2
Depreciation, amortization and accretion	168.7	191.7	229.6
Loss on long-lived assets, net	28.6	65.6	65.6
Goodwill impairment	0	38.8	162.6
Loss on contingent consideration	0	57	0
Total expenses	411.2	585.6	704.1
Operating income (loss)	113.5	(79.4)	(108.7)
Earnings from unconsolidated affiliates, net	53.3	47.8	31.5
Interest and debt expense, net	(99.2)	(99.4)	(125.1)
Gain (loss) on modification/extinguishment of debt	(0.9)	(37.7)	10
Other income, net	0.4	1.3	0.5
Income (loss) before income taxes	67.1	(167.4)	(191.8)
(Provision) benefit for income taxes	(0.1)	0.8	(0.3)
Net income (loss)	67	(166.6)	(192.1)
Net income attributable to non-controlling partner	(16.2)	(25.3)	(24.2)
Net income (loss) attributable to parent	50.8	(191.9)	(216.3)
Net income attributable to preferred units	60.1	62.5	28.7
Net loss attributable to partners	(9.3)	(254.4)	(245)
Common unitholders’ interest in net loss	$ (9.3)	$ (254.4)	$ (245)
Net loss per limited partner unit:
Basic (dollars per unit)	$ (0.13)	$ (3.64)	$ (3.55)
Diluted (dollars per unit)	$ (0.13)	$ (3.64)	$ (3.55)
Weighted-average limited partners’ units outstanding (in thousands):
Basic (units)	71,205	69,839	69,017
Dilutive units (units)	0	0	0
Diluted (units)	71,205	69,839	69,017
CMLP
Revenues:
Revenues	$ 3,654.1	$ 3,880.9	$ 2,520.5
Related party (Note 16)	1	1.8	2.6
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 16)	134.7	15.3	17.7
Total costs of products/services sold	3,129.4	3,374.7	1,925.1
Operating expenses and other:
Operations and maintenance	125.8	136	155
General and administrative	83.5	93.1	85.6
Depreciation, amortization and accretion	181.4	202.7	240.5
Loss on long-lived assets, net	28.6	65.6	65.6
Goodwill impairment	0	38.8	162.6
Loss on contingent consideration	0	57	0
Total expenses	419.3	593.2	709.3
Operating income (loss)	105.4	(87)	(113.9)
Earnings from unconsolidated affiliates, net	53.3	47.8	31.5
Interest and debt expense, net	(99.2)	(99.4)	(125.1)
Gain (loss) on modification/extinguishment of debt	(0.9)	(37.7)	10
Other income, net	0	0.8	0
(Provision) benefit for income taxes	0	0	0
Net income (loss)	58.6	(175.5)	(197.5)
Net income attributable to non-controlling partner	(16.2)	(25.3)	(24.2)
Net income (loss) attributable to parent	42.4	(200.8)	(221.7)
Service
Revenues:
Revenues	344.4	418.7	550.7
Costs of product/services sold (exclusive of items shown separately below):
Cost of Goods and Services Sold	44.2	49.9	55.5
Service | CMLP
Revenues:
Revenues	344.4	418.7	550.7
Costs of product/services sold (exclusive of items shown separately below):
Cost of Goods and Services Sold	44.2	49.9	55.5
Product
Revenues:
Revenues	3,309.7	3,462.2	1,969.8
Costs of product/services sold (exclusive of items shown separately below):
Cost of Goods and Services Sold	2,950.5	3,309.5	1,851.9
Product | CMLP
Revenues:
Revenues	3,309.7	3,462.2	1,969.8
Costs of product/services sold (exclusive of items shown separately below):
Cost of Goods and Services Sold	2,950.5	3,309.5	1,851.9
Gathering and Processing Segment | Service
Revenues:
Revenues	276.1	317.3	290.7
Gathering and Processing Segment | Service | CMLP
Revenues:
Revenues	276.1	317.3	290.7
Gathering and Processing Segment | Product
Revenues:
Revenues	670.5	1,369.1	825.5
Gathering and Processing Segment | Product | CMLP
Revenues:
Revenues	670.5	1,369.1	825.5
Marketing Supply and Logistics
Revenues:
Revenues	2,690.3	2,155.5	1,236.4
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold	2,362.2	1,893.6	1,003
Operating expenses and other:
Operations and maintenance	50.8	63.4	59.7
General and administrative	0	0	0
Loss on long-lived assets, net	27.3	48.2	31.4
Goodwill impairment		38.8	109.1
Loss on contingent consideration		0
Earnings from unconsolidated affiliates, net	0	0	0
Marketing Supply and Logistics | CMLP
Revenues:
Revenues	2,690.3	2,155.5	1,236.4
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold	2,362.2	1,893.6	1,003
Operating expenses and other:
Operations and maintenance	50.8	63.4	59.7
General and administrative	0	0	0
Loss on long-lived assets, net	27.3	48.2	31.4
Goodwill impairment		38.8	109.1
Loss on contingent consideration		0
Earnings from unconsolidated affiliates, net	0	0	0
Marketing Supply and Logistics | Service
Revenues:
Revenues	50.2	62.4	92.1
Marketing Supply and Logistics | Service | CMLP
Revenues:
Revenues	50.2	62.4	92.1
Marketing Supply and Logistics | Product
Revenues:
Revenues	2,639.2	2,093.1	1,144.3
Marketing Supply and Logistics | Product | CMLP
Revenues:
Revenues	2,639.2	2,093.1	1,144.3
Storage and Transportation
Revenues:
Revenues	17.1	37.2	165.3
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold	0.2	0.3	5.1
Operating expenses and other:
Operations and maintenance	3.3	4.2	21.4
General and administrative	0	0	0
Loss on long-lived assets, net	0	0	32.2
Goodwill impairment		0	44.9
Loss on contingent consideration		57
Earnings from unconsolidated affiliates, net	30.8	28.9	11.2
Storage and Transportation | CMLP
Revenues:
Revenues	17.1	37.2	165.3
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold	0.2	0.3	5.1
Operating expenses and other:
Operations and maintenance	3.3	4.2	18.3
General and administrative	0	0	0
Loss on long-lived assets, net	0	0	32.2
Goodwill impairment		0	44.9
Loss on contingent consideration		57
Earnings from unconsolidated affiliates, net	30.8	28.9	11.2
Storage and Transportation | Service
Revenues:
Revenues	17.1	37.2	165.3
Storage and Transportation | Service | CMLP
Revenues:
Revenues	$ 17.1	$ 37.2	$ 165.3

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 67	$ (166.6)	$ (192.1)
Change in fair value of Suburban Propane Partners, L.P. units	(0.7)	(0.8)	0.8
Comprehensive income (loss)	66.3	(167.4)	(191.3)
Comprehensive income (loss) attributable to non-controlling partners	(16.2)	(25.3)	(24.2)
Comprehensive income (loss) attributable to Crestwood Equity Partners LP	$ 50.1	$ (192.7)	$ (215.5)

Consolidated Statement of Partn

Consolidated Statement of Partners' Capital - USD ($) $ in Millions	Total	CMLP	Preferred Units	Common Unit Capital	Common Unit CapitalCMLP	Limited Partners	Limited PartnersCMLP	Non-Controlling Partners	Non-Controlling PartnersCMLP	Partners' Capital [Member]	Subordinated units	Common units	Preferred Units
Common Unit, Outstanding											400,000	68,200,000
Preferred units, outstanding													60,700,000
Balance at the beginning of the period at Dec. 31, 2015		$ 3,165.1	$ 535.8			$ 2,227.6	$ 2,981.6	$ 183.5	$ 183.5	$ 2,946.9
Increase (Decrease) in Partners' Capital [Roll Forward]
Unit-based compensation charges		19.2	0			19.2	19.2	0	0	19.2
Partners' Capital Account, Units, Unit-based Compensation												900,000
Taxes paid for unit-based compensation vesting		(0.8)	0			(0.8)	(0.8)	0	0	(0.8)
Distributions to partners		(242.8)	0			(219.8)	(227.6)	(15.2)	(15.2)	(235)
Preferred Stock Dividends, Shares													5,800,000
Change in fair value of Suburban Propane Partners, LP units			0			0.8		0		0.8
Net income (loss)	$ (192.1)	(197.5)	28.7			(245)	(221.7)	24.2	24.2	(192.1)
Balance at the end of the period at Dec. 31, 2016		2,743.2	564.5			1,782	2,550.7	192.5	192.5	2,539
Common Unit, Outstanding											400,000	69,100,000
Preferred units, outstanding													66,500,000
Increase (Decrease) in Partners' Capital [Roll Forward]
Proceeds from the issuance of common units			0	$ 15.2				0		15.2
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	$ 0	(202.7)	0	0				(202.7)	(202.7)	(202.7)
Partners' Capital Account, Units, Sold in Public Offering	633,271											600,000
Unit-based compensation charges		25.5	0			25.5	25.5	0	0	25.5
Partners' Capital Account, Units, Unit-based Compensation												800,000
Taxes paid for unit-based compensation vesting		(5.5)	0			(5.5)	(5.5)	0	0	(5.5)
Shares Paid for Tax Withholding for Share Based Compensation												(200,000)
Distributions to partners		(189.2)	(15)			(167.6)	(174)	(15.2)	(15.2)	(197.8)
Issuance of preferred equity of subsidiary	$ 0	175	0	0				175	175	175
Preferred Stock Dividends, Shares													4,800,000
Change in fair value of Suburban Propane Partners, LP units			0			(0.8)		0		(0.8)
Other		(0.4)	0	(0.9)	$ (0.5)			0.1	0.1	(0.8)
Net income (loss)	(166.6)	(175.5)	62.5			(254.4)	(200.8)	25.3	25.3	(166.6)
Balance at the end of the period at Dec. 31, 2017	$ 2,180.5	2,370.4	612			1,393.5	2,195.4	175	175	2,180.5
Common Unit, Outstanding											400,000	70,300,000
Preferred units, outstanding	71,257,445												71,300,000
Increase (Decrease) in Partners' Capital [Roll Forward]
Preferred units, issued	71,257,445
Proceeds from the issuance of common units								0
Partners' Capital Account, Units, Sold in Public Offering	0
Unit-based compensation charges		28.5	0			28.5	28.5	(9.9)	0	28.5
Partners' Capital Account, Units, Unit-based Compensation												1,100,000
Taxes paid for unit-based compensation vesting		(7.4)	0			(7.4)	(7.4)	0	0	(7.4)
Shares Paid for Tax Withholding for Share Based Compensation												(200,000)
Distributions to partners		(248.3)	(60.1)			(170.8)	(238.4)		(9.9)	(240.8)
Change in fair value of Suburban Propane Partners, LP units			0			(0.7)		0		(0.7)
Other		0.2	0	(0.8)	0.2			0	0	(0.8)
Net income (loss)	$ 67	58.6	60.1			(9.3)	42.4	16.2	16.2	67
Balance at the end of the period at Dec. 31, 2018	$ 2,033.8	2,209.5	612			$ 1,240.5	$ 2,028.2	181.3	181.3	2,033.8
Common Unit, Outstanding											400,000	71,200,000
Preferred units, outstanding	71,257,445												71,300,000
Increase (Decrease) in Partners' Capital [Roll Forward]
Preferred units, issued	71,257,445
Cumulative Effect of New Accounting Principle in Period of Adoption		$ 7.5	$ 0	$ 7.5	$ 7.5			$ 0	$ 0	$ 7.5

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating activities
Net income (loss)	$ 67	$ (166.6)	$ (192.1)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	168.7	191.7	229.6
Amortization of deferred financing costs	6.8	7.2	6.9
Unit-based compensation charges	28.5	25.5	19.2
Loss on long-lived assets, net	28.6	65.6	65.6
Goodwill impairment	0	38.8	162.6
Loss on contingent consideration	0	57	0
(Gain) loss on modification/extinguishment of debt	0.9	37.7	(10)
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	0.5	(0.1)	7.6
Deferred income taxes	(0.7)	(2.1)	(3.1)
Other	0.2	0.9	1.9
Changes in operating assets and liabilities:
Accounts receivable	167.8	(170.7)	(76.9)
Inventory	(24.1)	(9.9)	(22.5)
Prepaid expenses and other current assets	(3.1)	1.8	9.2
Accounts payable, accrued expenses and other liabilities	(138.6)	140.1	74.6
Reimbursements of property, plant and equipment	21.7	19.6	26
Change in price risk management activities, net	(70.6)	19.4	47.5
Net cash provided by operating activities	253.6	255.9	346.1
Investing activities
Acquisitions, net of cash acquired	0	0	(7.2)
Purchases of property, plant and equipment	(305.5)	(188.4)	(100.7)
Investment in unconsolidated affiliates	(64.4)	(58)	(12.4)
Capital distributions from unconsolidated affiliates	49.2	59.9	14.8
Net proceeds from sale of assets	79.5	225.2	972.7
Net cash provided by (used in) investing activities	(241.2)	38.7	867.2
Financing activities
Proceeds from the issuance of long-term debt	2,274.8	2,838.6	1,565.3
Payments on long-term debt	(2,015.7)	(2,913.9)	(2,536.3)
Payments on capital leases	(1.6)	(2.7)	(1.9)
Payments for deferred financing costs	(5.7)	(1)	(3.5)
Redemption of non-controlling interest	0	(202.7)	0
Net proceeds from issuance of non-controlling interest	0	(175)	0
Distributions to partners	(170.8)	(167.6)	(219.8)
Distributions to non-controlling partner	(9.9)	(15.2)	(15.2)
Distributions to preferred unitholders	60.1	15	0
Net proceeds from issuance of common units	0	15.2	0
Taxes paid for unit-based compensation vesting	(7.4)	(5.5)	(0.8)
Other	(0.1)	(0.1)	0
Net cash provided by (used in) financing activities	3.5	(294.9)	(1,212.2)
Net change in cash and restricted cash	15.9	(0.3)	1.1
Cash and restricted cash at beginning of period	1.3	1.6	0.5
Cash and restricted cash at end of period	17.2	1.3	1.6
Supplemental disclosure of cash flow information
Cash paid during the period for interest	97.4	95.1	121.5
Cash paid during the period for income taxes	3.1	3.1	1.4
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	0.3	(20.4)	(10.5)
CMLP
Operating activities
Net income (loss)	58.6	(175.5)	(197.5)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	181.4	202.7	240.5
Amortization of deferred financing costs	6.8	7.2	6.9
Unit-based compensation charges	28.5	25.5	19.2
Loss on long-lived assets, net	28.6	65.6	65.6
Goodwill impairment	0	38.8	162.6
Loss on contingent consideration	0	57	0
(Gain) loss on modification/extinguishment of debt	0.9	37.7	(10)
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	0.5	(0.1)	7.6
Deferred income taxes	(0.1)	0	0.2
Other	0.2	0.9	1.9
Changes in operating assets and liabilities:
Accounts receivable	169.3	(170.5)	(76.9)
Inventory	(24.1)	(9.9)	(22.5)
Prepaid expenses and other current assets	(3.1)	1.8	7.5
Accounts payable, accrued expenses and other liabilities	(138.1)	142	75.2
Reimbursements of property, plant and equipment	21.7	19.6	26
Change in price risk management activities, net	(70.6)	19.4	47.5
Net cash provided by operating activities	260.5	262.2	353.8
Investing activities
Acquisitions, net of cash acquired	0	0	(7.2)
Purchases of property, plant and equipment	(305.5)	(188.4)	(100.7)
Investment in unconsolidated affiliates	(64.4)	(58)	(12.4)
Capital distributions from unconsolidated affiliates	49.2	59.9	14.8
Net proceeds from sale of assets	79.5	225.2	972.7
Net cash provided by (used in) investing activities	(241.2)	38.7	867.2
Financing activities
Proceeds from the issuance of long-term debt	2,274.8	2,838.6	1,565.3
Payments on long-term debt	(2,015.7)	(2,913.9)	(2,536.1)
Payments on capital leases	(1.6)	(2.7)	(1.9)
Payments for deferred financing costs	(5.7)	(1)	(3.5)
Redemption of non-controlling interest	0	(202.7)	0
Net proceeds from issuance of non-controlling interest	0	(175)	0
Distributions to partners	(238.4)	(174)	(227.6)
Distributions to non-controlling partner	(9.9)	(15.2)	(15.2)
Taxes paid for unit-based compensation vesting	(7.4)	(5.5)	(0.8)
Other	0.1	0.2	0
Net cash provided by (used in) financing activities	(3.8)	(301.2)	(1,219.8)
Net change in cash and restricted cash	15.5	(0.3)	1.2
Cash and restricted cash at beginning of period	1	1.3	0.1
Cash and restricted cash at end of period	16.5	1	1.3
Supplemental disclosure of cash flow information
Cash paid during the period for interest	97.4	95.1	121.5
Cash paid during the period for income taxes	0.6	0.6	0.7
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$ 0.3	$ (20.4)	$ (10.5)

Organization and Description of

Organization and Description of Business	12 Months Ended
	Dec. 31, 2018
Disclosure Partnership Organization And Basis Of Presentation Narrative [Abstract]
Organization and Description of Business	Organization and Description of Business The accompanying notes to the consolidated financial statements apply to Crestwood Equity Partners LP (the Company, Crestwood Equity or CEQP) and Crestwood Midstream Partners LP (Crestwood Midstream or CMLP) unless otherwise indicated. Organization Crestwood Equity Partners LP . CEQP is a publicly-traded (NYSE: CEQP) Delaware limited partnership formed in March 2001. Crestwood Equity GP LLC, which is indirectly owned by Crestwood Holdings LLC (Crestwood Holdings), owns our non-economic general partnership interest. Crestwood Holdings, which is substantially owned and controlled by First Reserve Management, L.P. (First Reserve), also owns approximately 25% of Crestwood Equity’s common units and all of its subordinated units. Crestwood Midstream Partners LP . Crestwood Equity owns a 99.9% limited partnership interest in Crestwood Midstream and Crestwood Gas Services GP LLC (CGS GP), a wholly-owned subsidiary of Crestwood Equity, owns a 0.1% limited partnership interest in Crestwood Midstream. Crestwood Midstream GP LLC, a wholly-owned subsidiary of Crestwood Equity, owns the non-economic general partnership interest of Crestwood Midstream. The diagram below reflects a simplified version of our ownership structure as of December 31, 2018 : 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. Description of Business Crestwood Equity develops, acquires, owns or controls, and operates primarily fee-based assets and operations within the energy midstream sector. We provide broad-ranging infrastructure solutions across the value chain to service premier liquids-rich natural gas and crude oil shale plays across the United States. We own and operate a diversified portfolio of crude oil and natural gas gathering, processing, storage and transportation assets and connect fundamental energy supply with energy demand across North America. Crestwood Equity is a holding company and all of its consolidated assets are owned by or through its wholly-owned subsidiary, Crestwood Midstream. Our financial statements reflect three operating and reporting segments described below. • Gathering and Processing . Our gathering and processing (G&P) operations provide gathering and transportation services (natural gas, crude oil and produced water) and processing, treating and compression services (natural gas) to producers in unconventional shale plays and tight-gas plays in North Dakota, West Virginia, Texas, New Mexico, Wyoming and Arkansas. This segment primarily includes (i) our operations that own crude oil, rich and dry gas gathering systems, produced water gathering systems and processing plants in the Bakken, Marcellus, Barnett and Fayetteville Shale plays; and (ii) joint ventures that own rich and dry gas gathering systems and processing plants in the Delaware Permian and Powder River Basin (PRB) Niobrara Shale plays. • Storage and Transportation . Our storage and transportation (S&T) operations provide crude oil and natural gas storage and transportation services to producers, utilities and other customers. This segment primarily includes (i) our integrated crude oil loading, storage and pipeline terminal located in the heart of the Bakken and Three Forks Shale oil-producing areas in Williams County, North Dakota (the COLT Hub); and (ii) joint ventures that own regulated natural gas storage and transportation facilities in New York and Pennsylvania, natural gas storage facilities in Texas and a crude-by-rail terminal in Wyoming. • Marketing, Supply and Logistics . Our marketing, supply and logistics (MS&L) operations provide NGL and crude oil storage, marketing and transportation services to producers, refiners, marketers and other customers. This segment primarily includes (i) our fleet of rail and rolling stock, which includes our rail-to-truck NGL terminals located in Florida, New Jersey, New York, North Carolina and Rhode Island, and our truck maintenance facilities located in Indiana, Mississippi, New Jersey and Ohio; (ii) our Bath and Seymour NGL storage facilities located in New York and Indiana; and (iii) our crude oil and produced water transportation assets.

Basis of Presentation and Summa

Basis of Presentation and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Basis of Presentation and Summary of Significant Accounting Policies	Basis of Presentation and Summary of Significant Accounting Policies Basis of Presentation Our consolidated financial statements are prepared in accordance with GAAP and include the accounts of all consolidated subsidiaries after the elimination of all intercompany accounts and transactions. Certain amounts in prior periods have been reclassified to conform to the current year presentation, none of which impacted our previously reported net income, earnings per unit or partners’ capital. 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. Significant Accounting Policies Principles of Consolidation We consolidate entities when we have the ability to control or direct the operating and financial decisions of the entity or when we have a significant interest in the entity that gives us the ability to direct the activities that are significant to that entity. The determination to consolidate or apply the equity method of accounting to an entity can also require us to evaluate whether that entity is considered a variable interest entity (VIE). This evaluation, along with the determination of our ability to control, direct or exert significant influence over an entity involves the use of judgment. We apply the equity method of accounting where we can exert significant influence over, but do not control or direct the policies, decisions or activities of an entity and in the case of a VIE, are not the primary beneficiary. We use the cost method of accounting where we are unable to exert significant influence over the entity. All of our consolidated entities and equity method investments are not VIEs except for our investment in Crestwood Permian Basin Holdings LLC (Crestwood Permian). In October 2016, Crestwood Infrastructure Holdings LLC (Crestwood Infrastructure), our wholly-owned subsidiary, and an affiliate of First Reserve formed the Crestwood Permian joint venture to fund and own the Nautilus gathering system and other potential investments in the Delaware Permian. Crestwood Permian is a VIE because it did not have sufficient equity at risk to fund its activities at its inception (i.e., the construction of the Nautilus gathering system) without additional capital contributions from us and First Reserve, and CEQP has provided a guarantee to a third party that requires CEQP to fund 100% of the costs to build the Nautilus gathering system if Crestwood Permian fails to do so. We account for our investment in Crestwood Permian as an equity method investment because we are not the primary beneficiary of the VIE as of December 31, 2018 and 2017 . See Note 6 for a further discussion of our investment in Crestwood Permian. Use of Estimates The preparation of our consolidated financial statements in conformity with GAAP requires the use of estimates and assumptions that affect the amounts we report as assets, liabilities, revenues and expenses and our disclosures in these consolidated financial statements. Actual results can differ from those estimates. Cash We consider all highly liquid investments with an original maturity of less than three months to be cash. Restricted Cash On January 1, 2018, we adopted the provisions of ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force) which changed the classification and presentation of restricted cash in the statement of cash flows. The standard requires us to include restricted cash in our total cash when reconciling the beginning of period and end of period amounts shown on our consolidated statements of cash flows. The retrospective application of this ASU did not have an impact on our consolidated statements of cash flows for the years ended December 31, 2017 and 2016. Our restricted cash represents cash held under the terms of certain contractual agreements and is classified as current on our consolidated balance sheets. The change in restricted cash for the year ended December 31, 2018 is approximately $16.3 million and is included in operating activities (change in accounts payable, accrued expenses and other liabilities) in the consolidated statements of cash flows. Inventory Inventory for our marketing, supply and logistics operations are stated at the lower of cost or net realizable value and cost is computed predominantly using the average cost method. Our inventory consists primarily of crude oil and NGLs of approximately $64.2 million and $67.9 million at December 31, 2018 and 2017 . Property, Plant and Equipment Property, plant and equipment is recorded at is original cost of construction or, upon acquisition, at the fair value of the assets acquired. For assets we construct, we capitalize direct costs, such as labor and materials, and indirect costs, such as overhead and interest. We capitalize major units of property replacements or improvement and expense minor items. Depreciation is computed by the straight-line method over the estimated useful lives of the assets, as follows: Years Gathering systems and pipelines 15 - 20 Facilities and equipment 3 - 25 Buildings, rights-of-way and easements 1 - 40 Office furniture and fixtures 5 - 10 Vehicles 5 We depleted salt deposits included in our property, plant and equipment utilizing the unit of production method prior to their sale in December 2017. We evaluate our long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If such events or changes in circumstances are present, a loss is recognized if the carrying value of the asset is in excess of the sum of the undiscounted cash flows expected to result from the use of the asset and its eventual disposition. An impairment loss is measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset, which is typically based on discounted cash flow projections using assumptions as to revenues, costs and discount rates typical of third party market participants, which is a Level 3 fair value measurement. We did not record impairments of our property, plant and equipment during the year ended December 31, 2018 and 2016 . During 2017, we incurred $81.4 million of impairments of our property, plant and equipment related to our MS&L West Coast operations, which resulted from decreasing the forecasted cash flows to be generated by those operations. At December 31, 2017 , our estimates of fair value considered a number of factors, including the potential value if we sold the asset, a 12% discount rate and projected cash flows, which is a Level 3 fair value measurement. During 2018, we sold our MS&L West Coast operations for $70.5 million , and recorded a loss on long-lived assets of approximately $26.9 million (including $9.0 million related to the write off of goodwill). See “ Goodwill ” below and Note 3 for further information on the sale of these assets. Projected cash flows of our property, plant and equipment are generally based on current and anticipated future market conditions, which require significant judgment to make projections and assumptions about pricing, demand, competition, operating costs, constructions costs, legal and regulatory issues and other factors that may extend many years into the future and are often outside of our control. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. Identifiable Intangible Assets Our identifiable intangible assets consist of customer accounts, covenants not to compete, trademarks and certain revenue contracts. Customer accounts, covenants not to compete, trademarks and certain of our revenue contracts have arisen from acquisitions. We amortize certain of our revenue contracts based on the projected cash flows associated with these contracts if the projected cash flows are readily determinable, otherwise we amortize our revenue contracts on a straight-line basis. We recognize acquired intangible assets separately if the benefit of the intangible asset is obtained through contractual or other legal rights, or if the intangible asset can be sold, transferred, licensed, rented or exchanged, regardless of the acquirer’s intent to do so. We did not record impairments of our intangible assets during the year ended December 31, 2018 . During 2017 and 2016, we recorded the following impairments of our intangible assets and we reflected these impairments in loss on long-lived assets in our consolidated statements of operations: • During 2017, we fully impaired $0.8 million of intangible assets related to our MS&L West Coast operations, which resulted from decreasing forecasted cash flows to be generated by those operations. During 2018, we sold our MS&L West Coast operations for $70.5 million , and recorded a $26.9 million of loss on long-lived assets associated with the sale. See Note 3 for further information on the sale of these assets. • During 2016, we incurred a $31.4 million impairment of intangible assets related to our MS&L Trucking operations, which resulted from the impact of increased competition on our Trucking business and the loss of several key customer relationships that were acquired in 2013 to which the intangible assets related. Projected cash flows of our intangible assets are generally based on current and anticipated future market conditions, which require significant judgment 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. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. Certain intangible assets are amortized on a straight-line basis over their estimated economic lives, as follows: Weighted-Average Life (years) Customer accounts and revenue contracts 20 Trademarks 10 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. We also compare the total fair value of our reporting units to our overall enterprise value, which considers the market value for our common and preferred units. 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. We acquired substantially all of our reporting units in 2013, 2012 and 2011, which required us to record the assets, liabilities and goodwill of each of those reporting units at fair value on the date they were acquired. 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. Current commodity prices are significantly lower compared to commodity prices during 2014, and that decrease has adversely impacted forecasted cash flows, discount rates and stock/unit prices for most companies in the midstream industry, including us. As a result, we recorded goodwill impairments on several of our reporting units during 2017 and 2016. We did not record impairments of our goodwill during the year ended December 31, 2018 . At December 31, 2018 , our accumulated goodwill impairments at CEQP and CMLP were approximately $1,656.5 million and $1,399.3 million , respectively. The following table summarizes the goodwill of our various reporting units ( in millions ): Goodwill Impairments during the Year Ended December 31, 2016 Goodwill at January 1, 2017 Impact of Sale of US Salt Goodwill Impairments during the Year Ended December 31, 2017 Goodwill at December 31, 2017 Other Impact of Sale of West Coast Goodwill at December 31, 2018 G&P Marcellus $ 8.6 $ — $ — $ — $ — $ — $ — $ — Arrow — 45.9 — — 45.9 — — 45.9 S&T COLT 44.9 — — — — — — — MS&L NGL Marketing and Logistics — — — — — 101.7 (2) (9.0 ) (1) 92.7 West Coast — 2.4 — 2.4 — — — — Supply and Logistics 65.5 101.7 — — 101.7 (101.7 ) (2) — — Storage and Terminals 14.1 36.4 — 36.4 — — — — US Salt — 12.6 (12.6 ) (1) — — — — — Trucking 29.5 — — — — — — — Total $ 162.6 $ 199.0 $ (12.6 ) $ 38.8 $ 147.6 $ — $ (9.0 ) $ 138.6 (1) In December 2017, we sold 100% of our equity interests in US Salt to an affiliate of Kissner Group Holdings LP. In October 2018, we sold our West Coast assets and wrote off the goodwill attributable to these assets as further discussed below. (2) Reflects the combination of the MS&L reporting units into one NGL Marketing and Logistics reporting unit as further discussed below. On January 1, 2018, we combined the four reporting units included in the MS&L segment into one NGL Marketing and Logistics reporting unit for the purpose of evaluating goodwill for impairment on an ongoing basis. We combined these reporting units based on a strategic shift in the way in which we manage, operate and report our NGL operations as an integrated platform instead of as four individual stand-alone operations. We allocated approximately $9.0 million of the goodwill associated with our NGL Marketing and Logistics reporting unit to the West Coast facilities during 2018, and this goodwill was included in the loss on the sale of the West Coast assets. See Note 3 for a further discussion of the sale of our West Coast assets. The goodwill impairments recorded during 2017 related to our MS&L West Coast and Storage and Terminals operations. The goodwill impairment related to our MS&L West Coast operations resulted from decreasing forecasted cash flows to be generated by those operations. Our West Coast customers experienced headwinds during 2017, with both producers and refineries located in the Western U.S. experiencing regulatory challenges and an inflow of NGLs from the Eastern U.S., which caused demand for gathering, processing and logistics services from our West Coast operations to remain relatively flat over the past several years. The goodwill impairment related to our MS&L Storage and Terminals operations resulted from decreasing forecasted cash flows to be generated by those operations. During 2017, we experienced NGL market headwinds in the Northeast with NGL exports and other market dynamics causing price differentials to narrow between purchasing NGLs in the summer (which are then stored in our NGL facilities) and selling NGLs in the winter. These dynamics also caused the rates that we are able to charge for storing NGLs in our facilities to decline from their historical levels. Although our MS&L Storage and Terminals operations’ results have been relatively consistent over the past several years, these operations have not experienced growth as fast or to the decrease that we expected when we merged with Inergy, LP in 2013, and during 2017, we revised our forecasted cash flows to reflect current market dynamics, which we believe will continue for the foreseeable future. We utilized the income approach to determine the fair value of our reporting units given the limited availability of comparable market-based transactions during 2017, and we utilized discount rates ranging from 10% to 12% in applying the income approach to determine the fair value of our reporting units with goodwill as of December 31, 2017, which is a Level 3 fair value measurement. The goodwill impairments recorded during 2016 related to our G&P Marcellus operations, our MS&L Supply and Logistics and Storage and Terminals operations, our S&T COLT operations and our MS&L Trucking operations. The 2016 goodwill impairments on our Marcellus, Supply and Logistics, and Storage and Terminals operations primarily resulted from increasing the discount rates utilized in determining the fair value of those reporting units considering the significant decrease in the market price of our common units during the first quarter of 2016 and the continued decrease in commodity prices and its impact on the midstream industry and our customers. The 2016 goodwill impairments on our COLT and Trucking operations also resulted from those factors, but in addition they were impacted by (i) the expiration of two key crude-by-rail loading contracts during the fourth quarter of 2016, and the impact of those expirations on our projected future cash flows from our COLT operations; and (ii) the continued impact of increased competition on our Trucking business, a change in management in late 2016, and the planned downsizing of the excess capacity in our trucking fleet and operations and the impact that these had on our projected future cash flows from our Trucking operations. Although certain of these operations experienced increases in their operating results from 2013 to 2016, we decreased the cash flow forecasts for those businesses from the expectations when they were acquired in 2012 and 2013 based on our current assessment of the impact that the prolonged low commodity price environment is expected to have on demand for future services provided by those operations. We utilized the income approach to determine the fair value of our reporting units given the limited availability of comparable market-based transactions during 2016, and we utilized discount rates ranging from 10% to 19% in applying the income approach to determine the fair value of our reporting units with goodwill as of December 31, 2016, which is a Level 3 fair value measurement. Investments in Unconsolidated Affiliates Equity method investments in which we exercise significant influence, but do not control and are not the primary beneficiary, are accounted for using the equity method of accounting. Differences in the basis of investments and the separate net asset values of the investees, if any, are amortized into net income or loss over the remaining useful lives of the underlying assets and liabilities, except for the excess related to goodwill. 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, or if we decide to sell an investment in unconsolidated affiliate, we adjust the carrying values of the asset downward, if necessary, to their estimated fair values. We did not record impairments of our equity method investments during the years ended December 31, 2018, 2017 and 2016. Asset Retirement Obligations An asset retirement obligation (ARO) is an estimated liability for the cost to retire a tangible asset. We record a liability for legal or contractual obligations to retire our long-lived assets associated with our facilities and right-of-way contracts we hold. We record a liability in the period the obligation is incurred and estimable. An ARO is initially recorded at its estimated fair value with a corresponding increase to property, plant and equipment. This increase in property, plant and equipment is then depreciated over the useful life of the asset to which that liability relates. An ongoing expense is recognized for changes in the fair value of the liability as a result of the passage of time, which we record as depreciation, amortization and accretion expense on our consolidated statements of operations. We have various obligations to remove property, plant and equipment on rights-of-way and leases for which we cannot currently estimate the fair value of those obligations because the associated assets have indeterminate lives. An asset retirement obligation liability (and related assets), if any, will be recorded for these obligations once sufficient information is available to reasonably estimate the fair value of the obligations. At December 31, 2018 and 2017 , our AROs were reflected in other long-term liabilities on our consolidated balance sheets. See Note 5 for a further discussion of our AROs. Deferred Financing Costs Deferred financing costs represent costs associated with obtaining long-term financing and are amortized over the term of the related debt using a method which approximates the effective interest method and has a weighted average life of five years. Our net deferred financing costs are reflected as a reduction of long-term debt on our consolidated balance sheets. Revenue Recognition We provide gathering, processing, compression, storage, fractionation, and transportation (consisting of pipelines, truck and rail terminals, truck/trailer units and rail cars) services and we sell commodities (including crude oil, natural gas, NGLs and water) under various contracts. These contracts include: • Fixed-fee contracts . Under these contracts, we do not take title to the underlying crude oil, natural gas or NGLs but charge our customers a fixed-fee for the services we provide, which can be a firm reservation charge and/or a charge per volume gathered, processed, compressed, stored, loaded and/or transported (which, in certain contracts, can be subject to a minimum level of volumes); • Percentage-of-proceeds service contracts . Under these contracts, we take title to crude oil, natural gas or NGLs after the commodity leaves our gathering and processing facilities. We often market and sell those commodities to third parties after they leave our facilities and we will remit a portion of the sales proceeds to our producers; • Percentage-of-proceeds product contracts. Under these contracts, we take title to crude oil, natural gas or NGLs before the commodity enters our facilities. We market and sell those commodities to third parties and we will remit a portion of the sales proceeds to our producers; and • Purchase and sale contracts . Under these contracts, we purchase crude oil, natural gas or NGLs before the commodity enters our facilities, and we market and sell those commodities to third parties. On January 1, 2018, we adopted the provisions of ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers. We adopted the standard using the modified retrospective method for all revenue contracts that involve revenue generating activities that occur after January 1, 2018. Results for reporting periods beginning after January 1, 2018 are presented under the new standard, while amounts prior to January 1, 2018 continue to be reported in accordance with our historic accounting under Revenue Recognition (Topic 605) . Prior to January 1, 2018, we recognized revenues for services and products when all of the following criteria were met under Topic 605 : (i) services had been rendered or products delivered or sold; (ii) persuasive evidence of an exchange arrangement existed; (iii) the price for services was fixed or determinable; and (iv) collectability was reasonably assured. We recorded deferred revenue when we received amounts from our customers but had not yet met the criteria listed above. We recognized deferred revenue in our consolidated statement of operations when the criteria had been met and all services had been rendered. At December 31, 2017, we had deferred revenue of approximately $0.6 million , which is reflected in accrued expenses and other liabilities on our consolidated balance sheet. Beginning January 1, 2018, we recognize revenues for services and products under revenue contracts as our obligations to perform services or deliver/sell products under the contracts are satisfied. A contract’s transaction price is allocated to each performance obligation in the contract and recognized as revenue when, or as, the performance obligation is satisfied. Our fixed-fee contracts and our percentage-of-proceeds service contracts primarily have a single performance obligation to deliver a series of distinct goods or services that are substantially the same and have the same pattern of transfer to our customers. For performance obligations associated with these contracts, we recognize revenues over time utilizing the output method based on the actual volumes of products delivered/sold or services performed, because the single performance obligation is satisfied over time using the same performance measure of progress toward satisfaction of the performance obligation . The transaction price under certain of our fixed-price contracts and percentage-of-proceeds service contracts includes variable consideration that varies primarily based on actual volumes that are delivered under the contracts. Because the variable consideration specifically relates to our efforts to transfer the services and/or products under the contracts, we allocate the variable consideration entirely to the distinct service utilizing the allocation exception guidance under Topic 606 , and accordingly recognize the variable consideration as revenues at the time the good or service is transferred to the customer. Certain of our fixed-fee contracts contain minimum volume features under which the customers must utilize our services to gather, compress or load a specified quantity of crude oil or natural gas or pay a deficiency fee based on the difference between actual volumes and the contractual minimum volume. We recognize revenues from these contracts when actual volumes are gathered, compressed or loaded and the likelihood of a customer exercising its remaining rights to make up the deficient volumes under minimum volume commitments becomes remote. We recognize revenues at a point in time for performance obligations associated with our percentage-of proceeds product contracts and purchase and sale contracts, and these revenues are recognized because control of the underlying product is transferred to the customer when the distinct good is provided to the customer. The evaluation of when performance obligations have been satisfied and the transaction price that is allocated to our performance obligations requires significant judgments and assumptions, including our evaluation of the timing of when control of the underlying good or service has transferred to our customers and the relative standalone selling price of goods and services provided to customers under contracts with multiple performance obligations. Actual results can significantly vary from those judgments and assumptions. We did not have any material contracts with multiple performance obligations or under which we receive material amounts of non-cash consideration during the year ended December 31, 2018 . The following table summarizes the transaction price allocated to our remaining performance obligations under certain contracts that have not been recognized as of December 31, 2018 (in millions) : 2019 $ 32.5 2020 23.5 2021 9.4 2022 7.3 2023 7.3 Thereafter 3.3 Total $ 83.3 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. Contract Assets and Contract Liabilities . Amounts due from our customers under our revenue contracts are typically billed as the service is being provided or on a weekly, bi-weekly or monthly basis and are due within 30 days of billing. Under certain of our contracts, we recognize revenues in excess of billings which we present as contract assets on our consolidated balance sheets. Under certain contracts, we may be entitled to receive payments in advance of satisfying our performance obligations under the contract. We recognize a liability for these payments in excess of revenue recognized and present it as deferred revenue or contract liabilities on our consolidated balance sheets. Our deferred revenue primarily relates to: • Capital Reimbursements. Certain contracts in our G&P segment require that our customers reimburse us for capital expenditures related to the construction of long-lived assets utilized to provide services to them under the revenue contracts. Because we consider these amounts as consideration from customers associated with ongoing services to be provided to customers, we defer these upfront payments in deferred revenue and recognize the amounts in revenue over the life of the associated revenue contract as the performance obligations are satisfied under the contract. On January 1, 2018, we recorded an $87.6 million increase to our property, plant and equipment, net, a $69.1 million increase to our deferred revenue liability and an $18.5 million increase to partners’ capital as a result of applying the cumulative impact of adopting the new standard on these types of contracts. • Contracts with Increasing (Decreasing) Rates per Unit. Certain contracts in our G&P, S&T and MS&L segments have fixed rates per volume that increase and/or decrease over the life of the contract once certain time periods or thresholds are met. We record revenues on these contracts ratably per unit over the life of the contract based on the remaining performance obligations to be performed, which can result in the deferral of revenue for the difference between the consideration received and the ratable revenue recognized. On January 1, 2018, we recorded a $1.5 million increase to our deferred revenue liability and a corresponding decrease to partners’ capital as a result of applying the cumulative impact of adopting the new standard on these types of contracts. 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 Topic 606 revenue contracts totaled $209.7 million for both CEQP and CMLP at December 31, 2018 , and are included in accounts receivable on our consolidated balance sheet. Our contract assets are included in other non-current assets on our consolidated balance sheet. 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 i

Divestitures

Divestitures	12 Months Ended
	Dec. 31, 2018
Business Combinations [Abstract]
Divestitures	Divestitures In October 2018, we sold our West Coast assets to a third party for proceeds of approximately $70.5 million . The West Coast assets included a gas gathering and processing system, fractionator, butamer and various rail and truck terminal and storage facilities located in California, Nevada, Wyoming and Utah. The sale of West Coast resulted in a decrease of $61.8 million of property, plant and equipment, net, $9.0 million of goodwill and $26.6 million of other assets and liabilities, net. During the year ended December 31, 2018, we recognized a loss from the sale of approximately $26.9 million (including the goodwill write off discussed in Note 2), which was included in loss on long-lived assets in our consolidated statement of operations. Our West Coast assets were previously included in our MS&L segment. In December 2017, we sold 100% of our equity interests in US Salt, a solution-mining and salt production company located on the shores of Seneca Lake near Watkins Glen in Schuyler County, New York, to an affiliate of Kissner Group Holdings LP, for net proceeds of approximately $223.6 million . The sale of US Salt resulted in a decrease of $157.4 million of property, plant and equipment, net, $12.6 million of goodwill, $5.8 million of intangible assets and $14.2 million of other assets and liabilities, net. During the year ended December 31, 2017, we recognized a gain from the sale of approximately $33.6 million (including the goodwill write off discussed in Note 2, which was included in gain (loss) on long-lived assets in our consolidated statement of operations. US Salt was previously included in our MS&L segment.

Certain Balance Sheet Informati

Certain Balance Sheet Information	12 Months Ended
	Dec. 31, 2018
Balance Sheet Related Disclosures [Abstract]
Certain Balance Sheet Information	Certain Balance Sheet Information Property, Plant and Equipment Property, plant and equipment consisted of the following at December 31, 2018 and 2017 ( in millions ): CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Gathering systems and pipelines and related assets $ 758.6 $ 678.0 $ 901.5 $ 820.9 Facilities and equipment 1,230.7 1,141.4 1,415.9 1,326.5 Buildings, land, rights-of-way, storage rights and easements 331.7 319.1 335.4 322.8 Vehicles 17.9 37.3 16.1 35.5 Construction in process 230.8 87.5 230.8 87.5 Office furniture and fixtures 28.4 21.9 28.5 22.1 2,598.1 2,285.2 2,928.2 2,615.3 Less: accumulated depreciation and depletion 568.4 464.4 725.9 607.8 Total property, plant and equipment, net $ 2,029.7 $ 1,820.8 $ 2,202.3 $ 2,007.5 Depreciation. CEQP’s depreciation expense totaled $123.6 million , $135.9 million and $154.8 million for the years ended December 31, 2018 , 2017 and 2016 . CMLP’s depreciation expense totaled $137.7 million , $150.0 million and $168.9 million for the years ended December 31, 2018 , 2017 and 2016 . Depletion expense at both CEQP and CMLP totaled $0.7 million for the years ended December 31, 2017 and 2016 . We had no depletion expense for the year ended December 31, 2018. Capitalized Interest. During the years ended December 31, 2018 , 2017 and 2016 , CEQP and CMLP capitalized interest of $5.0 million , $2.9 million and $0.7 million related to certain expansion projects. Capital Leases. We had capital lease assets of $9.7 million and $2.1 million included in property, plant and equipment, net at December 31, 2018 and 2017, primarily related to certain vehicle leases. Intangible Assets Intangible assets consisted of the following at December 31, 2018 and 2017 ( in millions ): CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Customer accounts $ 438.9 $ 438.9 $ 438.9 $ 438.9 Gas gathering, compression and processing contracts 325.2 325.2 325.2 325.2 Trademarks (1) 6.2 24.7 6.2 9.2 770.3 788.8 770.3 773.3 Less: accumulated amortization 216.5 191.6 216.5 177.6 Total intangible assets, net $ 553.8 $ 597.2 $ 553.8 $ 595.7 (1) As of December 31, 2018, we fully amortized and eliminated certain intangibles associated with our trademarks. The following table summarizes total accumulated amortization of our intangible assets at December 31, 2018 and 2017 ( in millions ): CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Customer accounts $ 112.1 $ 89.8 $ 112.1 $ 89.8 Gas gathering, compression and processing contracts 100.8 82.0 100.8 82.0 Trademarks 3.6 19.8 3.6 5.8 Total accumulated amortization $ 216.5 $ 191.6 $ 216.5 $ 177.6 Crestwood Equity’s amortization expense related to its intangible assets for the years ended December 31, 2018 , 2017 and 2016 , was approximately $43.5 million , $53.7 million and $72.5 million . Crestwood Midstream’s amortization expense related to its intangible assets for the years ended December 31, 2018 , 2017 and 2016 was approximately $42.1 million , $50.6 million and $69.3 million . Estimated amortization of CEQP’s and CMLP’s intangible assets for the next five years is as follows ( in millions ): Year Ending December 31, 2019 $ 41.7 2020 41.7 2021 41.7 2022 41.7 2023 37.7 Accrued Expenses and Other Liabilities Accrued expenses and other liabilities consisted of the following at December 31, 2018 and 2017 ( in millions ): CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Accrued expenses (1) $ 64.8 $ 56.6 $ 63.7 $ 55.5 Accrued property taxes 2.6 4.8 2.6 4.8 Income tax payable 0.3 0.3 0.3 0.3 Interest payable 19.8 20.3 19.8 20.3 Accrued additions to property, plant and equipment 10.5 22.3 10.5 22.2 Capital leases 2.4 1.0 2.4 1.0 Deferred revenue 12.0 0.6 12.0 0.6 Total accrued expenses and other liabilities $ 112.4 $ 105.9 $ 111.3 $ 104.7 (1) Includes $16.2 million of related party accrued expenses at December 31, 2018 related to deposits received from Jackalope, our 50% equity method investment.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	Asset Retirement Obligations We have legal obligations associated with our facilities and right-of-way contracts we hold. Where we can reasonably estimate the asset retirement obligation, we accrue a liability based on an estimate of the timing and amount of settlement. We record changes in these estimates based on changes in the expected amount and timing of payments to settle our obligations. The following table presents the changes in the net asset retirement obligations for the years ended December 31, 2018 and 2017 ( in millions ): December 31, 2018 2017 Net asset retirement obligation at January 1 $ 27.5 $ 27.8 Liabilities incurred 0.7 — Liabilities settled (2.2 ) (1.2 ) Accretion expense 1.6 1.4 Change in estimate — (0.5 ) Net asset retirement obligation at December 31 $ 27.6 $ 27.5 We did not have any material assets that were legally restricted for use in settling asset retirement obligations as of December 31, 2018 and 2017 .

Investments in Unconsolidated A

Investments in Unconsolidated Affiliates	12 Months Ended
	Dec. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Investments in Unconsolidated Affiliates	Investments in Unconsolidated Affiliates Net Investments and Earnings (Loss) Our net investments in and earnings (loss) from our unconsolidated affiliates are as follows ( in millions, unless otherwise stated): Ownership Percentage Investment Earnings (Loss) from Unconsolidated Affiliates December 31, December 31, Year Ended December 31, 2018 2018 2017 2018 2017 2016 Stagecoach Gas Services LLC 50.00 % $ 830.4 $ 849.8 $ 29.3 $ 25.3 $ 15.9 Jackalope Gas Gathering Services, L.L.C. (1) 50.00 % (1) 210.2 184.9 18.1 10.5 20.8 Crestwood Permian Basin Holdings LLC (2) 50.00 % 104.3 102.0 4.4 8.4 (0.5 ) Tres Palacios Holdings LLC 50.01 % 35.0 37.8 — 2.2 (0.3 ) Powder River Basin Industrial Complex, LLC (3) 50.01 % 8.3 8.5 1.5 1.4 (4.4 ) Total $ 1,188.2 $ 1,183.0 $ 53.3 $ 47.8 $ 31.5 (1) Excludes non-controlling interest related to our investment in Jackalope. See Note 12 for a further discussion of our non-controlling interest related to our investment in Jackalope. (2) Pursuant to the Crestwood Permian limited liability company agreement, we were allocated 100% of Crestwood New Mexico’s earnings through June 30, 2018. Effective July 1, 2018, our equity earnings from Crestwood New Mexico is based on our ownership percentage of Crestwood Permian, which is currently 50% . (3) During the year ended December 31, 2016 , we recorded a reduction of our equity earnings from PRBIC of approximately $5.8 million related to impairments recorded by our equity investee. For a further discussion of these impairments, see Note 2 . Description of Investments Stagecoach Gas Services LLC On June 3, 2016, Crestwood Northeast and CEGP formed Stagecoach Gas Services LLC (Stagecoach Gas) to own and further develop our NE S&T assets. During 2016, we contributed to Stagecoach Gas the entities owning the natural gas storage and transportation business located in the Northeast (NE S&T assets). Additionally, CEGP contributed $975 million to Stagecoach Gas in exchange for a 50% equity interest in Stagecoach Gas, and Stagecoach Gas distributed to us the cash proceeds received (net of approximately $3 million of cash and restricted cash transferred to the joint venture) from CEGP. We deconsolidated the NE S&T assets as a result of this transaction discussed above and began accounting for our 50% equity interest in Stagecoach Gas under the equity method of accounting. We recognized a loss of approximately $32.4 million on the deconsolidation of the NE S&T assets. Our Stagecoach Gas investment is included in our storage and transportation segment. Pursuant to the Stagecoach Gas limited liability company agreement, we may be required to make payments of up to $57 million to CEGP 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 other third-party expansion projects, and during 2017, 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 sheets reflect an other long-term liability of $57 million at December 31, 2018 and 2017 , and our consolidated income statement for the year ended December 31, 2017 reflects a $57 million loss on contingent consideration related to this obligation. Jackalope Gas Gathering Services, L.L.C. Crestwood Niobrara LLC (Crestwood Niobrara), our consolidated subsidiary, owns a 50% ownership interest in Jackalope which we account for under the equity method of accounting. Williams Partners LP operates and owns the remaining 50% interest in Jackalope. Crestwood Niobrara manages the commercial operations of the Jackalope system. Our Jackalope investment is included in our gathering and processing segment. On January 1, 2018, Jackalope adopted the provisions of Topic 606 , and we recorded a $9.5 million decrease to our equity method investment and a corresponding decrease to our partners’ capital to reflect our proportionate share of the cumulative effect of accounting change recorded by Jackalope related to the new standard. In addition, our earnings from unconsolidated affiliates decreased by approximately $9.7 million during the year ended December 31, 2018 to reflect our proportionate share of Jackalope’s deferred revenues related to the new standard. Crestwood Permian Basin Holdings LLC In October 2016, Crestwood Infrastructure, our wholly-owned subsidiary, and an affiliate of First Reserve formed a joint venture, Crestwood Permian, to fund and own the Nautilus gathering system (described below) and other potential investments in the Delaware Permian. As part of this transaction, we transferred to the Crestwood Permian joint venture 100% of the equity interest of Crestwood Permian Basin LLC (Crestwood Permian Basin), which owns the Nautilus gathering system. We manage and account for our 50% ownership interest in Crestwood Permian, which is a VIE, 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. Our Crestwood Permian investment is included in our gathering and processing segment. Crestwood Permian Basin has a long-term agreement with SWEPI LP (SWEPI), a subsidiary of Royal Dutch Shell plc, to construct, own and operate a natural gas gathering system (the Nautilus gathering system) in SWEPI’s operated position in the Delaware Permian. SWEPI has dedicated to Crestwood Permian Basin the gathering rights for SWEPI’s gas production across a large acreage position in Loving, Reeves and Ward Counties, Texas. Crestwood Permian Basin provides gathering, dehydration, compression and liquids handling services to SWEPI on a fixed-fee basis. In conjunction with the Crestwood Permian Basin’s agreement with SWEPI, Crestwood Permian granted Shell Midstream Partners L.P. (Shell Midstream), a subsidiary of Royal Dutch Shell plc, an option to purchase up to 50% equity interest in Crestwood Permian Basin. In October 2017, Shell Midstream exercised its option and purchased a 50% equity interest in Crestwood Permian Basin from Crestwood Permian for approximately $37.9 million in cash. Crestwood Permian distributed to us approximately $18.9 million of the cash proceeds received. CEQP issued a guarantee in conjunction with the Crestwood Permian Basin gas gathering agreement with SWEPI described above, under which CEQP has agreed to fund 100% of the costs to build the Nautilus gathering system (which is estimated to cost approximately $180 million , of which approximately $145.6 million has been spent through December 31, 2018) if Crestwood Permian fails to do so. We do not believe this guarantee is probable of resulting 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 balance sheet at December 31, 2018 and 2017. On June 21, 2017, we contributed to Crestwood Permian 100% of the equity interest of Crestwood New Mexico, our wholly-owned subsidiary that owns our Delaware Basin assets located in Eddy County, New Mexico. This contribution was treated as a transaction between entities under common control (because of our relationship with First Reserve), and the accounting standards related to such transactions required Crestwood Permian to record the assets and liabilities of Crestwood New Mexico at our historical book value. Accordingly we deconsolidated Crestwood New Mexico and our investment in Crestwood Permian was increased by the historical book value of these assets of approximately $69.4 million . In conjunction with this contribution, First Reserve contributed to Crestwood Permian the first $151 million of capital costs required to fund the expansion of the Delaware Basin assets, which included a new processing plant located in Orla, Texas and associated pipelines that went into service in July 2018. Tres Palacios Holdings LLC Crestwood Midstream owns a 50.01% ownership interest in Tres Palacios Holdings LLC (Tres Holdings) and is the operator of Tres Palacios Gas Storage LLC (Tres Palacios) and its assets. Brookfield Infrastructure Group owns the remaining 49.99% ownership interest in Tres Holdings. We account for our investment in Tres Holdings under the equity method of accounting. Our Tres Holdings investment is included in our storage and transportation segment. Powder River Basin Industrial Complex, LLC Crestwood Crude Logistics LLC, our consolidated subsidiary, owns a 50% ownership interest in PRBIC which we account for under the equity method of accounting. Twin Eagle Powder River Basin, LLC owns the remaining 50% ownership interest in PRBIC. Our PRBIC investment is included in our storage and transportation segment Summarized Financial Information of Unconsolidated Affiliates Below is summarized financial information for our significant unconsolidated affiliates ( in millions; amounts represent 100% of unconsolidated affiliate information ): Financial Position Data December 31, 2018 2017 Current Assets Non-Current Assets Current Liabilities Non-Current Liabilities Members’ Equity Current Assets Non-Current Assets Current Liabilities Non-Current Liabilities Members’ Equity Stagecoach (1) $ 50.1 $ 1,725.1 $ 4.2 $ 0.9 $ 1,770.1 $ 55.1 $ 1,765.4 $ 7.0 $ 1.4 $ 1,812.1 Crestwood Permian (2) 17.7 372.6 16.8 94.7 278.8 37.6 203.3 33.4 1.8 205.7 Other (3) 59.3 658.0 17.4 129.6 570.3 43.7 597.8 20.0 91.8 529.7 Total $ 127.1 $ 2,755.7 $ 38.4 $ 225.2 $ 2,619.2 $ 136.4 $ 2,566.5 $ 60.4 $ 95.0 $ 2,547.5 (1) As of December 31, 2018 , our equity in the underlying net assets of 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. (2) As of December 31, 2018, the difference of approximately $8.9 million between our equity in Crestwood Permian’s net assets and our investment balance is not subject to amortization. (3) Includes our Jackalope, Tres Holdings and PRBIC equity investments. As of December 31, 2018 , our equity in the underlying net assets of Jackalope, Tres Holdings and PRBIC exceeded our investment balance by approximately $0.4 million , $25.3 million and $5.9 million , respectively. Operating Results Data Year Ended December 31, 2018 2017 2016 Operating Revenues Operating Expenses Net Income Operating Revenues Operating Expenses Net Income Operating Revenues Operating Expenses Net Income Stagecoach $ 171.4 $ 79.3 $ 92.1 $ 168.6 $ 77.7 $ 91.1 $ 99.3 $ 44.1 $ 55.3 Crestwood 82.2 81.3 5.7 87.3 74.1 14.1 11.5 10.9 0.6 Other (1) 116.9 81.5 35.6 94.5 69.5 24.8 116.1 103.0 12.9 Total $ 370.5 $ 242.1 $ 133.4 $ 350.4 $ 221.3 $ 130.0 $ 226.9 $ 158.0 $ 68.8 (1) Includes our Jackalope, Tres Holdings and PRBIC equity investments. 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 Jackalope equity investment of less than $0.1 million for each of the years ended December 31, 2018 , 2017 and 2016 , which we amortize over the life of Jackalope’s gathering agreement with Chesapeake Energy Corporation (Chesapeake). We recorded amortization of the excess basis in our Tres Holdings equity investment of approximately $1.3 million for each of the years ended December 31, 2018 , 2017 and 2016 , which we amortize over the life of Tres Palacios’ sublease agreement. We recorded amortization of the excess basis in our PRBIC equity investment of approximately $0.5 million , $0.6 million and $1.6 million for the years ended December 31, 2018 , 2017 and 2016 , which we amortize over the life of PRBIC’s property, plant and equipment. Distributions and Contributions Distributions Contributions Year Ended December 31, Year Ended December 31, 2018 2017 2016 2018 2017 2016 Stagecoach Gas $ 48.7 $ 47.3 $ 16.0 $ — $ 0.8 $ — Jackalope (1) 32.4 26.3 27.4 49.1 3.5 1.4 Crestwood Permian (2) 14.7 23.4 — 12.6 117.5 — Tres Holdings (3) 5.3 9.0 8.5 2.5 5.6 11.0 PRBIC (1) 1.9 1.6 2.0 0.2 — — Total $ 103.0 $ 107.6 $ 53.9 $ 64.4 $ 127.4 $ 12.4 (1) Jackalope and PRBIC are required to make quarterly distributions of its available cash to its members based on their respective ownership percentage. In February 2019, we received a cash distribution of $11.6 million from Jackalope. (2) On June 21, 2017, we contributed to Crestwood Permian 100% of the equity interest of Crestwood New Mexico at our historical book value of approximately $69.4 million . This contribution was treated as a non-cash transaction between entities under common control. (3) Tres Holdings is required, within 30 days following the end of each quarter, to make quarterly distributions of its available cash (as defined in its limited liability company agreement) to its members based on their respective ownership percentage. Stagecoach Gas . Stagecoach Gas is required, within 30 days following the end of each quarter, to distribute 60% and 40% of its available cash (as defined in its limited liability company agreement) to CEGP and us, respectively. Pursuant to the Stagecoach limited liability company agreement, our share of Stagecoach’s equity earnings increased from 35% to 40% effective July 1, 2018. Prior to July 1, 2018, Stagecoach Gas distributed 35% of its available cash to us. Because our ownership and distribution percentages differ, we determine the equity earnings from Stagecoach Gas using the Hypothetical Liquidation at Book Value (HLBV) method. Under the HLBV method, a calculation is prepared at each balance sheet date to determine the amount that we would receive if Stagecoach Gas were to liquidate all of its assets, as valued in accordance with GAAP, and distribute that cash to the members. The difference between the calculated liquidation distribution amounts at the beginning and the end of the reporting period, after adjusting for capital contributions and distributions, is our share of the earnings or losses from the equity investment for the period, which approximates how earnings are allocated under the terms of the limited liability company agreement. In January 2019, we received a cash distribution from Stagecoach Gas of approximately $13.0 million . Crestwood Permian . Crestwood Permian is required, within 30 days following the end of each quarter to distribute 100% of its available cash (as defined in its limited liability company agreement) to its members based on their respective ownership percentages. Pursuant to Crestwood Permian's limited liability company agreement, we received 100% of Crestwood New Mexico's available cash (as defined in the limited liability company agreement) through June 30, 2018, and subsequent to June 30, 2018, our distributions are based on the members respective ownership percentages. Because our ownership and distribution percentages will differ during this period, equity earnings from Crestwood Permian is determined using the HLBV method. Under the HLBV method, a calculation is prepared at each balance sheet date to determine the amount that we would receive if Crestwood Permian were to liquidate all of its assets, as valued in accordance with GAAP, and distribute that cash to the members. The difference between the calculated liquidation distribution amounts at the beginning and the end of the reporting period, after adjusting for capital contributions and distributions, is our share of the earnings or losses from the equity investment for the period, which approximates how earnings are allocated under the terms of the limited liability company agreement. In January 2019, we received a cash distribution from Crestwood Permian of approximately $2.3 million .

Risk Management

Risk Management	12 Months Ended
	Dec. 31, 2018
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 2 and Note 8 . Commodity Derivative Instruments and Price Risk Management Risk Management Activities We sell NGLs and crude oil to energy related businesses and may use a variety of financial and other instruments including forward contracts involving physical delivery of NGLs, heating oil and crude oil. 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 the 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 costs of products/services sold and operating revenues during the years ended December 31, 2018 , 2017 and 2016 ( in millions ): December 31, 2018 2017 2016 Gain (loss) reflected in costs of product/services sold $ 29.6 $ (31.2 ) $ (7.8 ) Product revenues 343.3 234.1 162.9 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: December 31, 2018 December 31, 2017 Fixed Price Payor Fixed Price Receiver Fixed Price Payor Fixed Price Receiver Propane, crude and heating oil (MMBbls) 27.8 30.1 15.3 17.5 Natural gas (MMcf) 1,800 1,800 780 660 Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly, notional amounts do not reflect our monetary exposure to market or credit risks. All contracts subject to price risk had a maturity of 36 months or less; however, 82% of the contracted volumes will be delivered or settled within 12 months . Credit Risk Inherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. The counterparties associated with our price risk management activities are energy marketers and propane retailers, resellers and dealers. Certain of our derivative instruments have credit limits that require us to post collateral. The amount of collateral required to be posted is a function of the net liability position of the derivative as well as our established credit limit with the respective counterparty. If our credit rating were to change, the counterparties could require us to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent of change in our credit rating as well as the requirements of the individual counterparty. In addition, we have margin requirements with a 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 represents the fair value of our commodity derivative instruments with credit-risk-related contingent features and their associated collateral ( in millions ): December 31, 2018 2017 Aggregate fair value of derivative instruments with credit-risk-related contingent features (1) $ 2.2 $ 28.9 NYMEX-related net derivative asset (liability) position (9.4 ) 27.2 NYMEX-related cash collateral posted 21.7 5.6 Cash collateral received 14.2 3.7 (1) At December 31, 2018 and 2017 . we posted less than less than $0.1 million of collateral associated with these derivatives.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2018
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 December 31, 2018 and 2017 , the carrying amounts of cash, accounts receivable and accounts payable approximate the fair value based on the short-term nature of these instruments. Credit Facility The fair value of the amounts outstanding under our CMLP credit facility approximates the carrying amounts as of December 31, 2018 and 2017 , 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 reflects the carrying amount (reduced for deferred financing costs associated with the respective notes) and fair value of our senior notes ( in millions ): December 31, 2018 December 31, 2017 Carrying Amount Fair Value Carrying Amount Fair 2023 Senior Notes $ 693.6 $ 668.1 $ 692.1 $ 728.8 2025 Senior Notes $ 493.4 $ 466.2 $ 492.3 $ 517.9 Financial Assets and Liabilities As of December 31, 2018 and 2017 , 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, and NGLs. 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 December 31, 2018 and 2017 ( in millions ): December 31, 2018 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 $ 12.4 $ 160.7 $ — $ 173.1 $ (140.3 ) $ 1.9 $ 34.7 Suburban Propane Partners, L.P. units (2) 2.8 — — 2.8 — — 2.8 Total assets at fair value $ 15.2 $ 160.7 $ — $ 175.9 $ (140.3 ) $ 1.9 $ 37.5 Liabilities Liabilities from price risk management $ 7.0 $ 144.7 $ — $ 151.7 $ (140.3 ) $ (5.6 ) $ 5.8 Total liabilities at fair value $ 7.0 $ 144.7 $ — $ 151.7 $ (140.3 ) $ (5.6 ) $ 5.8 December 31, 2017 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 $ 1.1 $ 102.2 $ — $ 103.3 $ (74.6 ) $ (21.5 ) $ 7.2 Suburban Propane Partners, L.P. units (2) 3.5 — — 3.5 — — 3.5 Total assets at fair value $ 4.6 $ 102.2 $ — $ 106.8 $ (74.6 ) $ (21.5 ) $ 10.7 Liabilities Liabilities from price risk management $ 1.4 $ 118.2 $ — $ 119.6 $ (74.6 ) $ 3.9 $ 48.9 Total liabilities at fair value $ 1.4 $ 118.2 $ — $ 119.6 $ (74.6 ) $ 3.9 $ 48.9 (1) Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions as well as cash collateral held or placed with the same counterparties. (2) Amount is reflected in other assets on CEQP’s consolidated balance sheets.

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2018
Text Block [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt consisted of the following at December 31, 2018 and 2017 , ( in millions ): December 31, 2018 2017 Credit Facility $ 578.2 $ 318.2 2023 Senior Notes 700.0 700.0 2025 Senior Notes 500.0 500.0 Other 1.5 2.4 Less: deferred financing costs, net 26.4 28.4 Total debt 1,753.3 1,492.2 Less: current portion 0.9 0.9 Total long-term debt, less current portion $ 1,752.4 $ 1,491.3 Credit Facility In October 2018, Crestwood Midstream entered into a Second Amended and Restated Agreement (the CMLP Credit Agreement). The CMLP Credit Agreement provides for a five -year $1.25 billion revolving credit facility (the CMLP Credit Facility), which expires in October 2023 and is available to fund acquisitions, working capital and internal growth projects and for general partnership purposes. The CMLP Credit Facility allows Crestwood Midstream to increase its available borrowings under the facility by $350.0 million , subject to lender approval and the satisfaction of certain other conditions, as described in the CMLP Credit Agreement. The CMLP Credit Facility also includes a sub-limit of up to $25.0 million for same-day swing line advances and a sub-limit up to $350.0 million for letters of credit. Subject to limited exception, the CMLP Credit Facility is guaranteed and secured by substantially all of the equity interests and assets of Crestwood Midstream’s subsidiaries, except for Crestwood Niobrara, Crestwood Infrastructure, PRBIC, Crestwood Northeast and Tres Holdings and their respective subsidiaries. The Company also guarantees Crestwood Midstream’s payment obligations under its $1.25 billion credit agreement. Prior to amending and restating its credit agreement in October 2018, Crestwood Midstream had a five-year $1.5 billion senior secured revolving credit facility, which would have expired September 2020 (2020 Credit Facility). We recognized a loss on modification of debt of approximately $0.9 million for the year ended December 31, 2018 in conjunction with amending and restating the CMLP Credit Agreement. Borrowings under the CMLP Credit Facility (other than the swing line loans) bear interest at either: • the Alternate Base Rate, which is defined as the highest of (i) the federal funds rate plus 0.50% ; (ii) Wells Fargo Bank’s prime rate; or (iii) the Eurodollar Rate adjusted for certain reserve requirements plus 1% ; plus a margin varying from 0.50% to 1.50% at December 31, 2018 depending on Crestwood Midstream’s most recent consolidated total leverage ratio; or • the Eurodollar Rate, adjusted for certain reserve requirements plus a margin varying from 1.50% to 2.50% at December 31, 2018 depending on Crestwood Midstream’s most recent consolidated total leverage ratio. Swing line loans bear interest at the Alternate Base Rate as described above. The unused portion of the CMLP Credit Facility is subject to a commitment fee ranging from 0.25% to 0.45% according to its most recent consolidated total leverage ratio. Interest on the Alternate Base Rate loans is payable quarterly, or if the adjusted Eurodollar Rate applies, interest is payable at certain intervals selected by Crestwood Midstream. At December 31, 2018 , Crestwood Midstream had $524.0 million of available capacity under its credit facility considering the most restrictive covenants in its credit agreement. At December 31, 2018 and 2017 , Crestwood Midstream’s outstanding standby letters of credit were $68.0 million and $52.2 million . Interest rates under the CMLP Credit Facility were between 4.63% and 6.75% at December 31, 2018 and the weighted-average interest on outstanding borrowings was 4.79% . Interest rates under the 2020 Credit Facility were between 3.94% and 6.00% at December 31, 2017 and the weighted-average interest rate on outstanding borrowings was 4.11% . The CMLP Credit Facility contains various covenants and restrictive provisions that limit our ability to, among other things, (i) incur additional debt; (ii) make distributions on or redeem or repurchase units; (iii) make certain investments and acquisitions; (iv) incur or permit certain liens to exist; (v) merge, consolidate or amalgamate with another company; (vi) transfer or dispose of assets; and (vii) incur a change in control at either Crestwood Equity or Crestwood Midstream, including an acquisition of Crestwood Holdings’ ownership of Crestwood Equity’s general partner by any third party, including Crestwood Holdings’ debtors under an event of default of their debt since Crestwood Equity’s non-economic general partner interest is pledged as collateral under that debt. 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 December 31, 2018 , the net debt to consolidated EBITDA was approximately 4.25 to 1.0, the consolidated EBITDA to consolidated interest expense was approximately 4.40 to 1.0, and the senior secured leverage ratio was 1.38 to 1.0. If Crestwood Midstream fails to perform its obligations under these and other covenants, the lenders’ credit commitment could be terminated and any outstanding borrowings, together with accrued interest, under the CMLP Credit Facility could be declared immediately due and payable. The CMLP Credit Facility also has cross default provisions that apply to any of its other material indebtedness. Senior Notes 2023 Senior Notes . The 6.25% Senior Notes due 2023 (the 2023 Senior Notes) mature on April 1, 2023, and interest is payable semi-annually in arrears on April 1 and October 1 of each year. 2025 Senior Notes. In March 2017, Crestwood Midstream issued $500 million of 5.75% unsecured senior notes due 2025 (the 2025 Senior Notes) in a private offering. The 2025 Senior Notes will mature on April 1, 2025, and interest is payable semi-annually in arrears on April 1 and October 1 of each year, beginning October 1, 2017. The net proceeds from this offering of approximately $492 million were used to repay amounts previously outstanding under CMLP’s senior notes due in 2020 and 2022 as discussed below. In May 2017, Crestwood Midstream filed a registration statement with the SEC under which is offered to exchange new senior notes for any and all outstanding 2025 Senior Notes. Crestwood Midstream completed the exchange offer in July 2017. The terms of the exchange notes are substantially identical to the terms of the 2025 Senior Notes, except that the exchange notes are freely tradable. In general, each series of Crestwood Midstream’s senior notes are fully and unconditionally guaranteed, joint and severally, on a senior unsecured basis by Crestwood Midstream’s domestic restricted subsidiaries (other than Finance Corp., which has no assets). The indentures contain customary release provisions, such as (i) disposition of all or substantially all the assets of, or the capital stock of, a guarantor subsidiary to a third person if the disposition complies with the indentures; (ii) designation of a guarantor subsidiary as an unrestricted subsidiary in accordance with its indentures; (iii) legal or covenant defeasance of a series of senior notes, or satisfaction and discharge of the related indenture; and (iv) guarantor subsidiary ceases to guarantee any other indebtedness of Crestwood Midstream or any other guarantor subsidiary, provided it no longer guarantees indebtedness under the CMLP Credit Facility. The indentures restricts the ability of Crestwood Midstream and its restricted subsidiaries to, among other things, sell assets; redeem or repurchase subordinated debt; make investments; incur or guarantee additional indebtedness or issue preferred units; create or incur certain liens; enter into agreements that restrict distributions or other payments to Crestwood Midstream from its restricted subsidiaries; consolidate, merge or transfer all or substantially all of their assets; engage in affiliate transactions; create unrestricted subsidiaries; and incur a change in control at either Crestwood Equity or Crestwood Midstream, including an acquisition of Crestwood Holdings’ ownership of Crestwood Equity’s general partner by any third party including Crestwood Holdings’ debtors under an event of default of their debt since Crestwood Equity’s non-economic general partner interest is pledged as collateral under that debt. These restrictions are subject to a number of exceptions and qualifications, and many of these restrictions will terminate when the senior notes are rated investment grade by either Moody’s Investors Service, Inc. or Standard & Poor’s Rating Services and no default or event of default (each as defined in the respective indentures) under the indentures has occurred and is continuing. At December 31, 2018 , Crestwood Midstream was in compliance with the debt covenants and restrictions in each of its credit agreements discussed above. Crestwood Midstream’s Credit Facility and its respective senior notes are secured by its assets and liabilities of the guarantor subsidiaries. Accordingly, such assets are only available to the creditors of Crestwood Midstream. Crestwood Equity had restricted net assets of approximately $2,028.2 million as of December 31, 2018 . Repayments. During the year ended December 31, 2017, Crestwood Midstream paid approximately $349.9 million and $457.8 million to purchase, redeem and/or cancel all of the principal amounts previously outstanding under CMLP’s senior notes due in 2020 and 2022, respectively. Crestwood Midstream funded the repayments with a combination of net proceeds from the issuance of the 2025 Senior Notes described above and borrowings under the 2020 Credit Facility. In conjunction with these note repayments, Crestwood Midstream (i) recognized a loss on extinguishment of debt of approximately $37.7 million during the year ended December 31, 2017 (including the write off of approximately $6.8 million of deferred financing costs associated with the senior notes due in 2022); and (ii) paid $5.1 million and $1.0 million of accrued interest on CMLP’s senior notes due in 2020 and 2022, respectively, on the date they were tendered. In June 2016, Crestwood Midstream paid approximately $312.9 million to purchase and cancel approximately $161.2 million and $163.6 million of the principal amounts previously outstanding under CMLP’s senior notes due in 2020 and 2022, respectively, utilizing a portion of the proceeds received from Stagecoach Gas, as further discussed in Note 6. During the year ended December 31, 2016, Crestwood Midstream recognized a gain on extinguishment of debt of approximately $10.0 million in conjunction with the early tender of these notes. Crestwood Midstream also paid $4.5 million and $2.6 million of accrued interest on CMLP’s senior notes due in 2020 and 2022, respectively, on the date they were tendered. Other Obligations Our non-interest bearing obligations due under noncompetition agreements consist of agreements between Crestwood Midstream and sellers of certain companies acquired in 2014 with payments due through 2022 and imputed interest ranging from 5.02% to 6.75% . Non-interest bearing obligations consisted of $1.7 million and $2.7 million in total payments due under these agreements, less unamortized discount based on imputed interest of $0.2 million and $0.3 million at December 31, 2018 and 2017 , respectively. Maturities The aggregate maturities of principal amounts on our outstanding long-term debt and other notes payable as of December 31, 2018 for the next five years and in total thereafter are as follows ( in millions ): 2019 $ 0.9 2020 0.2 2021 0.2 2022 0.2 2023 1,278.2 Thereafter 500.0 Total debt $ 1,779.7 Residual Value Guarantee In 2012, Crestwood Equity entered into a support agreement with Suburban Propane Partners, L.P. (SPH) pursuant to which Crestwood Equity is obligated to provide contingent, residual support of approximately $497 million of aggregate principal amount of the 7.5% senior unsecured notes due 2018 of SPH and Suburban Energy Finance Corp. (collectively, the SPH Issuers) or any permitted refinancing thereof. The support agreement was terminated on the maturity date of supported debt.

Earnings Per Limited Partner Un

Earnings Per Limited Partner Unit	12 Months Ended
	Dec. 31, 2018
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 years ended December 31, 2018 , 2017 and 2016 : Year Ended December 31, 2018 2017 2016 Preferred units (1) 7,125,744 7,007,917 6,433,127 Crestwood Niobrara’s preferred units (1) 6,526,495 7,146,663 7,548,624 Subordinated units (2) 438,789 438,789 438,789 Stock-based compensation performance units (2) 365,997 316,980 — (1) See Note 12 for additional information regarding the potential conversion of our preferred units and Crestwood Niobrara’s preferred units to common units. (2) For a description of our subordinated and stock-based compensation performance units, see Note 12 and Note 13 , respectively.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The (provision) benefit for income taxes for the years ended December 31, 2018 , 2017 , and 2016 consisted of the following (in millions) : CEQP CMLP Year Ended December 31, Year Ended December 31, 2018 2017 2016 2018 2017 (1) 2016 Current: Federal $ (0.5 ) $ (1.1 ) $ (3.2 ) $ 0.1 $ — $ — State (0.3 ) (0.2 ) (0.2 ) (0.2 ) — 0.2 Total current (0.8 ) (1.3 ) (3.4 ) (0.1 ) — 0.2 Deferred: Federal 0.5 2.1 3.0 — — — State 0.2 — 0.1 0.1 — (0.2 ) Total deferred 0.7 2.1 3.1 0.1 — (0.2 ) (Provision) benefit for income taxes $ (0.1 ) $ 0.8 $ (0.3 ) $ — $ — $ — (1) For the year ended December 31, 2017, our benefit for income taxes was not material to CMLP’s consolidated statement of operations. The effective rate differs from the statutory rate for the years ended December 31, 2018 , 2017 and 2016 , primarily due to the partnerships not being treated as a corporation for federal income tax purposes as discussed in Note 2 . Deferred income taxes related to CEQP’s wholly owned subsidiaries, IPCH Acquisition Corp. and Crestwood Gas Services GP LLC, and our Texas Margin tax which reflects the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. Components of our deferred income taxes at December 31, 2018 and 2017 are as follows (in millions). CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Deferred tax asset: Basis difference in stock of company $ 0.2 $ 0.2 $ — $ — Total deferred tax asset 0.2 0.2 — — Deferred tax liability: Basis difference in stock of company (2.8 ) (3.5 ) (0.6 ) (0.7 ) Total deferred tax liability (2.8 ) (3.5 ) (0.6 ) (0.7 ) Net deferred tax liability $ (2.6 ) $ (3.3 ) $ (0.6 ) $ (0.7 ) Uncertain Tax Positions. We evaluate the uncertainty in tax positions taken or expected to be taken in the course of preparing our consolidated financial statements to determine whether the tax positions are more likely than not of being sustained by the applicable tax authority. Such tax positions, if any, would be recorded as a tax benefit or expense in the current year. We believe that there were no uncertain tax positions that would impact our results of operations for the years ended December 31, 2018 , 2017 and 2016 and that no provision for income tax was required for these consolidated financial statements. However, our conclusions regarding the evaluation of uncertain tax positions are subject to review and may change based on factors including, but not limited to, ongoing analyses of tax laws, regulations and interpretations thereof.

Partners' Capital

Partners' Capital	12 Months Ended
	Dec. 31, 2018
Partners' Capital [Abstract]
Partners' Capital	Partners’ Capital Preferred Units Subject to certain conditions, the holders of the preferred units will have the right to convert preferred units into (i) common units on a 1-for-10 basis, or (ii) a number of common units determined pursuant to a conversion ratio set forth in our partnership agreement upon the occurrence of certain events, such as a change in control. The preferred units have voting rights that are identical to the voting rights of the common units and will vote with the common units as a single class, with each preferred units entitled to one vote for each common unit into which such preferred unit is convertible, except that the preferred units are entitled to vote as a separate class on any matter on which all unitholders are entitled to vote that adversely affects the rights, powers, privileges or preferences of the preferred units in relation to CEQP’s other securities outstanding. Common Units Equity Distribution Agreement. On August 4, 2017, we entered into an equity distribution agreement with certain financial institutions (each, a Manager), under which we may offer and sell from time to time through one or more of the Managers, common units having an aggregate offering price of up to $250 million . Common units sold pursuant to this at-the-market (ATM) equity distribution program are issued under a registration statement that became effective on April 12, 2017. We are required to pay the Managers an aggregate fee of up to 2.0% of the gross sales price per common unit sold under our ATM equity distribution program. There were no units issued under our ATM equity distribution program during the year ended December 31, 2018. During the year ended December 31, 2017, we issued 633,271 common units under the ATM equity distribution program for net proceeds of approximately $15.2 million . We paid a manager fee of approximately $0.3 million during the year ended December 31, 2017 related to the sale of the common units. Distributions Crestwood Equity Limited Partners . Crestwood Equity makes quarterly distributions to its partners within approximately 45 days after the end of each quarter in an aggregate amount equal to its available cash for such quarter. Available cash generally means, with respect to each quarter, all cash on hand at the end of the quarter less the amount of cash that the general partner determines in its reasonable discretion is necessary or appropriate to: • provide for the proper conduct of its business; • comply with applicable law, any of its debt instruments, or other agreements; or • provide funds for distributions to unitholders for any one or more of the next four quarters; plus all cash on hand on the date of determination of available cash for the quarter resulting from working capital borrowings made after the end of the quarter. The amount of cash CEQP has available for distribution depends primarily upon its cash flow (which consists of the cash distributions it receives in connection with its ownership of Crestwood Midstream). A summary of CEQP’s limited partner quarterly cash distributions for the years ended December 31, 2018 , 2017 and 2016 is presented below: Record Date Payment Date Per Unit Rate Cash Distributions ( in millions ) 2018 February 7, 2018 February 14, 2018 $ 0.60 $ 42.7 May 8, 2018 May 15, 2018 $ 0.60 42.7 August 7, 2018 August 14, 2018 $ 0.60 42.7 November 7, 2018 November 14, 2018 $ 0.60 42.7 $ 170.8 2017 February 7, 2017 February 14, 2017 $ 0.60 $ 41.8 May 8, 2017 May 15, 2017 $ 0.60 41.8 August 7, 2017 August 14, 2017 $ 0.60 41.8 November 7, 2017 November 14, 2017 $ 0.60 42.2 $ 167.6 2016 February 5, 2016 February 12, 2016 $ 1.375 $ 95.6 May 6, 2016 May 13, 2016 $ 0.60 41.4 August 5, 2016 August 12, 2016 $ 0.60 41.4 November 7, 2016 November 14, 2016 $ 0.60 41.4 $ 219.8 On February 14, 2019 , we paid a distribution of $0.60 per limited partner unit to unitholders of record on February 7, 2019 with respect to the fourth quarter of 2018 . Preferred UnitHolders . The holders of our preferred units are entitled to receive fixed quarterly distributions of $0.2111 per unit. Through the quarters ending September 30, 2017 (the Initial Distribution Period), distributions on the preferred units could be made in additional preferred units, cash, or a combination thereof, at our election. We paid distributions on our preferred units through the issuance of additional preferred units through and for the quarter ended June 30, 2017. The number of units distributed was calculated as the fixed quarterly distribution of $0.2111 per unit divided by the cash purchase price of $9.13 per unit. We accrued the fair value of such distribution at the end of the quarterly period and adjusted the fair value of the distribution on the date the additional preferred units were distributed. Distributions on the preferred units following the Initial Distribution Period will be paid in cash unless, subject to certain exceptions, (i) there is no distribution being paid on our common units; and (ii) our available cash (as defined in our partnership agreement) is insufficient to make a cash distribution to our preferred unitholders. If we fail to pay the full amount payable to our preferred unitholders in cash following the Initial Distribution Period, then (x) the fixed quarterly distribution on the preferred units will increase to $0.2567 per unit, and (y) we will not be permitted to declare or make any distributions to our common unitholders until such time as all accrued and unpaid distributions on the preferred units have been paid in full in cash. In addition, if we fail to pay in full any Preferred Distribution (as defined in our partnership agreement), the amount of such unpaid distribution will accrue and accumulate from the last day of the quarter for which such distribution is due until paid in full, and any accrued and unpaid distributions will be increased at a rate of 2.8125% per quarter. During the year ended December 31, 2018 , we made cash distributions to our preferred unitholders of approximately $60.1 million . In November 2017, we made a cash distribution to our preferred unitholders of approximately $15.0 million for the quarter ended September 30, 2017. During the years ended December 31, 2017 and 2016 , we issued 4,724,030 and 5,815,170 preferred units to our preferred unitholders in lieu of paying quarterly cash distributions of $43.1 million and $53.0 million . On February 14, 2019 , we made a cash distribution of approximately $15.0 million to our preferred unitholders for the quarter ended December 31, 2018 . In March 2018, Crestwood Equity registered 71,257,445 preferred units under a shelf registration statement filed with the SEC under which holders of the preferred units may sell their preferred units. The registration statement became effective in May 2018. Crestwood Midstream In accordance with the partnership agreement, Crestwood Midstream’s general partner may, from time to time, cause Crestwood Midstream to make cash distributions at the sole discretion of the general partner. During the years ended December 31, 2018 , 2017 and 2016 , Crestwood Midstream made distributions of $238.4 million , $174.0 million and $227.6 million , which represented net amounts due to Crestwood Midstream related to cash advances to CEQP for its general corporate activities. Non-Controlling Partner Crestwood Niobrara issued a preferred interest (Series A Preferred Units) to a subsidiary of General Electric Capital Corporation and GE Structured Finance, Inc. (collectively, GE) in conjunction with the acquisition of its investment in Jackalope, which is reflected as non-controlling interest in our consolidated financial statements. In December 2017, Crestwood Niobrara redeemed 100% of the outstanding Series A Preferred Units from GE for an aggregate purchase price of approximately $202.7 million and issued $175 million in new preferred interests (Series A-2 Preferred Units) to CN Jackalope Holdings LLC (Jackalope Holdings). In conjunction with the issuance of the Series A-2 Preferred Units, we entered into a Second Amended and Restated Limited Liability Company Agreement (Crestwood Niobrara Amended Agreement) with Crestwood Niobrara. Pursuant to the Crestwood Niobrara Amended Agreement, we serve as the managing member of Crestwood Niobrara and, subject to certain restrictions, we have the ability to redeem the Series A-2 Preferred Units for an amount in cash or CEQP common units equal to an amount necessary for Jackalope Holdings to achieve a certain rate of return. Also in conjunction with the Crestwood Niobrara Amended Agreement, we entered into a registration rights agreement with Jackalope Holdings. Pursuant to the registration rights agreement, we granted Jackalope Holdings certain rights with respect to CEQP’s common units issuable to Jackalope Holdings in certain circumstances as set forth in the Crestwood Niobrara Amended Agreement. During the years ended December 31, 2018 , 2017 , and 2016 , net income attributable to non-controlling partners was approximately $16.2 million , $25.3 million and $24.2 million . Crestwood Niobrara is required to make quarterly cash distributions on its preferred interest within 30 days after the end of each quarter. During the years ended December 31, 2018 , 2017 and 2016 , Crestwood Niobrara paid cash distributions of $9.9 million , $15.2 million and $15.2 million to its preferred interest owners. In January 2019, Crestwood Niobrara paid a cash distribution of $3.3 million to Jackalope Holdings for the quarter ended December 31, 2018. Other Partners’ Capital Transactions Subordinated Units In conjunction with Crestwood Holdings’ acquisition of Crestwood Equity’s general partner, Crestwood Equity issued 438,789 subordinated units, which are considered limited partnership interests, and have the same rights and obligations as its common units, except that the subordinated units are entitled to receive distributions of available cash for a particular quarter only after each of our common units has received a distribution of at least $1.30 for that quarter. The subordinated units convert to common units after (i) CEQP’s common units have received a cumulative distribution in excess of $5.20 during a consecutive four quarter period; and (ii) its Adjusted Operating Surplus (as defined in the agreement) exceeds the distribution on a fully dilutive basis.

Equity Plans

Equity Plans	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Equity Plan	Equity Plans Long-term incentive awards are granted under the Crestwood Equity Partners LP Long Term Incentive Plan (Crestwood LTIP) in order to align the economic interests of key employees and directors with those of CEQP’s common unitholders and to provide an incentive for continuous employment. Long-term incentive compensation consist of grants of restricted, phantom and performance units which vest based upon continued service. The following table summarizes information regarding restricted and phantom unit activity during the years ended December 31, 2018 , 2017 and 2016 . Units Weighted-Average Grant Date Fair Value Unvested - January 1, 2016 466,214 $ 69.80 Granted - restricted units 1,067,535 $ 14.58 Granted - phantom units 17,467 $ 15.54 Vested - restricted units (193,295 ) $ 76.82 Forfeited (65,591 ) $ 25.13 Unvested - December 31, 2016 1,292,330 $ 24.67 Granted - restricted units 919,411 $ 25.69 Granted - phantom units 15,849 $ 25.02 Granted - performance units 405,620 $ 30.21 Vested - restricted units (607,115 ) $ 28.00 Vested - performance units (31,106 ) $ 30.27 Forfeited - restricted units (140,137 ) $ 23.73 Forfeited - performance units (24,756 ) $ 30.45 Unvested - December 31, 2017 1,830,096 $ 25.21 Granted - restricted units 1,144,017 $ 25.80 Granted - phantom units 7,750 $ 26.10 Granted - performance units 901 $ 25.60 Vested - restricted units (617,807 ) $ 23.73 Vested - phantom units (105,809 ) $ 49.45 Vested - performance units (11,772 ) $ 28.87 Forfeited - restricted units (53,530 ) $ 23.36 Forfeited - phantom units (6 ) $ 49.45 Forfeited - performance units (5,870 ) $ 30.45 Unvested - December 31, 2018 2,187,970 $ 24.78 As of December 31, 2018 and 2017 , we had total unamortized compensation expense of approximately $28.0 million and $23.7 million related to restricted, phantom, and performance units, which will be amortized during the next three years (or sooner in certain cases, which generally represents the original vesting period of these instruments), except for grants to non-employee directors of our general partner, which vest over one year. We recognized compensation expense of approximately $24.3 million , $22.4 million and $16.0 million under the Crestwood LTIP during the years ended December 31, 2018 , 2017 and 2016 , which is included in general and administrative expenses on our consolidated statements of operations. As of February 11, 2019, we had 4,036,711 units available for issuance under the Crestwood LTIP. Restricted Units. Under the Crestwood LTIP, participants who have been granted restricted units may elect to have us withhold common units to satisfy minimum statutory tax withholding obligations arising in connection with the vesting of non-vested common units. Any such common units withheld are returned to the Crestwood LTIP on the applicable vesting dates, which correspond to the times at which income is recognized by the employee. When we withhold these common units, we are required to remit to the appropriate taxing authorities the fair value of the units withheld as of the vesting date. The number of units withheld is determined based on the closing price per common unit as reported on the NYSE on such dates. During the years ended December 31, 2018 , 2017 , and 2016 we withheld 221,576 , 206,600 and 57,508 common units to satisfy employee tax withholding obligations. Phantom Units. The Crestwood LTIP permits grants of phantom units that entitle the holder thereof to receive upon vesting one CEQP common unit granted pursuant to the Crestwood LTIP and a phantom unit award agreement (the Crestwood Equity Phantom Unit Agreement). The Crestwood Equity Phantom Unit Agreement provides for vesting to occur at the end of three years following the grant date or, if earlier, upon the named executive officer’s termination without cause or due to death or disability or the named executive officer’s resignation for employee cause (each, as defined in the Crestwood Equity Phantom Unit Agreement). In addition, the Crestwood Equity Phantom Unit Agreement provides for distribution equivalent rights with respect to each phantom unit which are paid in additional phantom units and settled in common units upon vesting of the underlying phantom units. Performance Units. The Crestwood LTIP permits grants of performance units that are designed to provide an incentive for continuous employment to certain key employees. Performance units vest over a three year performance period and the number of units issued are based on a performance multiplier ranging between 50% and 200% , determined based on the actual performance in the third year of the performance period compared to pre-established performance goals. The performance goals are based on achieving a specified level of distributable cash flow per unit, Adjusted EBITDA, return on capital invested, and three-year relative total shareholder return. 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. Employee Unit Purchase Plan In August 2018, the board of directors of our general partner approved an employee unit purchase plan under which employees of the general partner may purchase our common units through payroll deductions up to a maximum of 10% of the employees’ eligible compensation, not to exceed $25,000 for any calendar year. Under the plan, we anticipate purchasing our common units on the open market for the benefit of participating employees based on their payroll deductions. In addition, we may match up to 10% of participating employees’ payroll deductions to purchase additional Crestwood common units for participating employees. The board of directors of our general partner authorized 1,500,000 common units (subject to adjustment as provided in the employee unit purchase plan) to be available for purchase. There were no common units purchased under the employee unit purchase plan in 2018.

Employee Benefit Plan

Employee Benefit Plan	12 Months Ended
	Dec. 31, 2018
Postemployment Benefits [Abstract]
Employee Benefit Plans	Employee Benefit Plan A 401(k) plan is available to all of our employees after meeting certain requirements. The plan permits employees to make contributions up to 90% of their salary, up to statutory limits, which was $18,500 in 2018 , and $18,000 in 2017 and 2016 . We match 100% of participants basic contribution up to 6% of eligible compensation. Employees may participate in the plans immediately and certain employees are not eligible for matching contributions until after a 90 -day waiting period. Aggregate matching contributions made by us were $4.6 million , $4.0 million and $3.8 million during the years ended December 31, 2018 , 2017 and 2016 .

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Legal Proceedings California Trucking Lawsuit. On March 13, 2017, a former Crestwood truck driver filed a lawsuit in the Superior Court (the Court) for Kern County, California on behalf of all Crestwood Transportation LLC’s California drivers alleging that Crestwood Equity and its officers, directors and employees violated the California wage and hour laws by failing to comply with certain requirements of the laws. The settlement of this lawsuit was finalized in November 2018, and it did not have a material impact to our consolidated financial statements. 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 December 31, 2018 and 2017 , both CEQP and CMLP had $0.1 million and approximately $2.1 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 worker 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. 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 December 31, 2018 . At December 31, 2018 and 2017 , our accrual of approximately $1.8 million and $1.9 million is based on our undiscounted estimate of amounts we will spend on remediation and compliance with environmental and other regulations, and any associated fines or penalties (including the Arrow water releases described above). We estimate that our potential liability for reasonably possible outcomes related to our environmental exposures could range from approximately $1.8 million to $3.3 million at December 31, 2018 . 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 December 31, 2018 and 2017 (in millions) : CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Self-insurance reserves (1) $ 11.3 $ 13.6 $ 9.6 $ 11.6 (1) CEQP and CMLP classified approximately $7.5 million and $6.2 million of their respective balances as other long-term liabilities on their consolidated balance sheets at December 31, 2018 . Commitments and Purchase Obligations Operating Leases. We maintain operating leases in the ordinary course of our business activities. These leases include those for office buildings, crude oil railroad cars and other operating facilities and equipment. The terms of the agreements vary from 2019 until 2032. Our rent expense for operating leases for the years ended December 31, 2018 , 2017 and 2016 , totaled $13.9 million , $34.2 million and $25.5 million . Capital Leases. We also maintain capital leases in the ordinary course of our business activities. These leases primarily related to certain of our vehicle leases. The following table presents the future minimum lease payments under our noncancelable operating leases and the net minimum lease payments under our existing capital leases for the next five years ending December 31 and in total thereafter ( in millions ): Capital Leases Year Ending December 31, Operating Leases Minimum Lease Payments Less Interest Net Present Value Total 2019 $ 22.3 $ 3.0 $ 0.6 $ 2.4 $ 24.7 2020 18.1 3.3 0.4 2.9 21.0 2021 14.4 3.2 0.2 3.0 17.4 2022 9.7 1.9 0.1 1.8 11.5 2023 6.0 — — — 6.0 Thereafter 10.7 — — — 10.7 Total minimum lease payments $ 81.2 $ 11.4 $ 1.3 $ 10.1 $ 91.3 Purchase Commitments. We periodically enter into agreements with suppliers to purchase fixed quantities of NGLs, distillates, crude oil and natural gas at fixed prices. At December 31, 2018 , the total of these firm purchase commitments was $894.0 million , of which approximately $784.3 million will occur over the course of the next twelve months. We also enter into non-binding agreements with suppliers to purchase quantities of NGLs, distillates and natural gas at variable prices at future dates at the then prevailing market prices. We have entered into certain purchase commitments primarily related to our gathering and processing segment. At December 31, 2018 , our total purchase commitments were approximately $77.2 million , which primarily relate to future growth projects and maintenance obligations in our gathering and processing segment. The purchases associated with these commitments are expected to occur over the next twelve months. 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 6 . 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 December 31, 2018 , we have no amounts accrued for these guarantees.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2018
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions 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 and the services are based on the same terms as non-affiliates, including gas gathering and processing services under long-term contracts, product purchases and various operating agreements. We also enter into transactions with our affiliates related to services provided on our expansion projects. During the year ended December 31, 2018 and 2017, we paid approximately $7.2 million and $2.5 million of capital expenditures to Applied Consultants, Inc., an affiliate of Crestwood Holdings. Below is a discussion of certain of our related party agreements. Shared Services. CMLP shares common management, general and administrative and overhead costs with CEQP. CEQP grants long-term incentive awards under the Crestwood LTIP as discussed in Note 13 and, as such, CEQP allocates a portion of its unit-based compensation costs to CMLP. Stagecoach Gas Management Agreement. In May 2016, Crestwood Midstream Operations, LLC (Crestwood Midstream Operations), our wholly-owned subsidiary and Stagecoach Gas entered into a management agreement under which Crestwood Midstream Operations provides the management and operating services required by Stagecoach Gas’ facilities. The initial term of the agreement will expire in May 2021, and is automatically extended for three-year periods unless otherwise terminated pursuant to the terms of the agreement. Reimbursements received from Stagecoach Gas under this agreement are reflected as operations and maintenance expenses at CEQP and CMLP in the table below. Tres Palacios Operating Agreement. A consolidated subsidiary of Crestwood Midstream entered into an operating agreement with Tres Palacios, pursuant to which we assumed the responsibility of operating and maintaining the facilities as well as certain administrative and other general services identified in the agreement. Under the operating agreement, Tres Palacios reimburses us for all cost incurred on its behalf. These reimbursements are reflected as operations and maintenance expenses at CEQP and CMLP in the table below. Crestwood Permian Operating Agreement. In October 2016, Crestwood Midstream Operations entered into an operating agreement with Crestwood Permian, pursuant to which we provide operating services for Crestwood Permian’s facilities, as well as certain administrative and other general services identified in the agreement. Under this operating agreement, Crestwood Permian reimburses us for all costs incurred on its behalf. These reimbursements are reflected as operations and maintenance expenses at CEQP and CMLP in the table below. Jackalope Gas Gathering Services, L.L.C. A consolidated subsidiary of Crestwood Midstream entered into a marketing services agreement with Jackalope under which we provide marketing services for Jackalope as well as certain administrative and other general services identified in the agreement. Under this marketing services agreement, Jackalope reimburses us for all costs incurred on its behalf. These reimbursements are reflected as operations and maintenance expenses at CEQP and CMLP in the table below. The following table shows revenues, costs of product/services sold, general and administrative expenses and reimbursement of expenses from our affiliates for the years December 31, 2018 , 2017 and 2016 ( in millions ): Year Ended December 31, 2018 2017 2016 Revenues at CEQP and CMLP $ 1.0 $ 1.8 $ 2.6 Costs of product/services sold at CEQP and CMLP (1) $ 134.7 $ 15.3 $ 17.7 Operations and maintenance expenses at CEQP and CMLP (2) $ 28.7 $ 22.3 $ 8.1 General and administrative expenses charged by CEQP to CMLP, net (3) $ 20.7 $ 19.4 $ 13.0 General and administrative expenses at CEQP charged from Crestwood Holdings, net (4) $ (2.7 ) $ (1.7 ) $ (2.2 ) (1) Includes $56.1 million during the year ended December 31, 2018 related to purchases of NGLs from a subsidiary of Crestwood Permian and $78.6 million related to an agency marketing agreement with Ascent Resources - Utica, LLC (Ascent). Amounts presented for the years ended December 31, 2017 and 2016 represent natural gas purchases from Sabine Oil and Gas (Sabine). Ascent and Sabine are affiliates of Crestwood Holdings for the respective periods presented. (2) 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. During the year ended December 31, 2018, we charged $7.9 million to Stagecoach Gas, $3.8 million to Tres Palacios, $15.9 million to Crestwood Permian and $1.1 million to Jackalope. During the year ended December 31, 2017, we charged $8.4 million to Stagecoach Gas, $3.5 million to Tres Palacios, $10.0 million to Crestwood Permian and $0.4 million to Jackalope. During the year ended December 31, 2016, we charged $5.0 million to Stagecoach Gas, $2.7 million to Tres Palacios, and $0.4 million to Jackalope. (3) Includes $24.3 million , $22.4 million and $16.0 million of net unit-based compensation charges allocated from CEQP to CMLP for the years ended December 31, 2018 , 2017 and 2016 . In addition, includes $3.6 million , $3.0 million and $3.0 million of CMLP’s general and administrative costs allocated to CEQP during the years ended December 31, 2018 , 2017 and 2016 . (4) Includes $4.2 million , $3.1 million and $3.2 million of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the years ended December 31, 2018 , 2017 and 2016 . The following table shows accounts receivable and accounts payable from our affiliates as of December 31, 2018 and 2017 ( in millions ): December 31, 2018 2017 Accounts receivable at CEQP and CMLP $ 4.1 $ 7.1 Accounts payable at CEQP $ 16.1 $ 7.4 Accounts payable at CMLP $ 13.6 $ 5.0

Segments

Segments	12 Months Ended
	Dec. 31, 2018
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. For a further description of our operating and reporting segments, see Note 1. We assess the performance of our operating segments based on EBITDA, which is defined as income before income taxes, plus debt-related costs (net interest and debt expense and gain or loss on modification/extinguishment of debt) and depreciation, amortization and accretion expense. Below is a reconciliation of CEQP’s net income (loss) to EBITDA ( in millions ): Year Ended December 31, 2018 2017 2016 Net income (loss) $ 67.0 $ (166.6 ) $ (192.1 ) Add: Interest and debt expense, net 99.2 99.4 125.1 (Gain) loss on modification/extinguishment of debt 0.9 37.7 (10.0 ) Provision (benefit) for income taxes 0.1 (0.8 ) 0.3 Depreciation, amortization and accretion 168.7 191.7 229.6 EBITDA $ 335.9 $ 161.4 $ 152.9 Below is a reconciliation of CMLP’s net income (loss) to EBITDA ( in millions ): Year Ended December 31, 2018 2017 2016 Net income (loss) $ 58.6 $ (175.5 ) $ (197.5 ) Add: Interest and debt expense, net 99.2 99.4 125.1 (Gain) loss on modification/extinguishment of debt 0.9 37.7 (10.0 ) Depreciation, amortization and accretion 181.4 202.7 240.5 EBITDA $ 340.1 $ 164.3 $ 158.1 The following tables summarize CEQP’s and CMLP’s reportable segment data for the years ended December 31, 2018 , 2017 and 2016 ( in millions ). Intersegment revenues included in the following tables are accounted for as arms-length transactions that apply our revenue recognition policies described in Note 2 . Included in earnings from unconsolidated affiliates below was approximately $42.3 million , $32.5 million and $29.6 million of depreciation and amortization expense and gains (losses) on long-lived assets, net related to our equity investments for the years ended December 31, 2018 , 2017 and 2016 , respectively. Crestwood Equity Year Ended December 31, 2018 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Corporate Total Revenues $ 946.7 $ 17.1 $ 2,690.3 $ — $ 3,654.1 Intersegment revenues 192.4 10.5 (202.9 ) — — Costs of product/services sold 767.0 0.2 2,362.2 — 3,129.4 Operations and maintenance expense 71.7 3.3 50.8 — 125.8 General and administrative expense — — — 88.1 88.1 Gain (loss) on long-lived assets, net (3.0 ) — (27.3 ) 1.7 (28.6 ) Earnings from unconsolidated affiliates, net 22.5 30.8 — — 53.3 Other income, net — — — 0.4 0.4 EBITDA $ 319.9 $ 54.9 $ 47.1 $ (86.0 ) $ 335.9 Goodwill $ 45.9 $ — $ 92.7 $ — $ 138.6 Total assets $ 2,633.4 $ 1,004.4 $ 612.5 $ 44.2 $ 4,294.5 Purchases of property, plant and equipment $ 294.7 $ 0.6 $ 5.6 $ 4.6 $ 305.5 Year Ended December 31, 2017 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Corporate Total Revenues $ 1,688.2 $ 37.2 $ 2,155.5 $ — $ 3,880.9 Intersegment revenues 134.5 6.7 (141.2 ) — — Costs of product/services sold 1,480.8 0.3 1,893.6 — 3,374.7 Operations and maintenance expense 68.4 4.2 63.4 — 136.0 General and administrative expense — — — 96.5 96.5 Loss on long-lived assets, net (14.4 ) — (48.2 ) (3.0 ) (65.6 ) Goodwill impairment — — (38.8 ) — (38.8 ) Loss on contingent consideration — (57.0 ) — — (57.0 ) Earnings from unconsolidated affiliates, net 18.9 28.9 — — 47.8 Other income, net 0.8 — — 0.5 1.3 EBITDA $ 278.8 $ 11.3 $ (29.7 ) $ (99.0 ) $ 161.4 Goodwill $ 45.9 $ — $ 101.7 $ — $ 147.6 Total assets $ 2,474.1 $ 1,040.6 $ 757.1 $ 13.1 $ 4,284.9 Purchases of property, plant and equipment $ 162.7 $ 1.3 $ 17.7 $ 6.7 $ 188.4 Year Ended December 31, 2016 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Corporate Total Revenues $ 1,118.8 $ 165.3 $ 1,236.4 $ — $ 2,520.5 Intersegment revenues 108.6 4.2 (112.8 ) — — Costs of product/services sold 917.0 5.1 1,003.0 — 1,925.1 Operations and maintenance expense 77.0 21.4 59.7 — 158.1 General and administrative expense — — — 88.2 88.2 Loss on long-lived assets (2.0 ) (32.2 ) (31.4 ) — (65.6 ) Goodwill impairment (8.6 ) (44.9 ) (109.1 ) — (162.6 ) Earnings from unconsolidated affiliates, net 20.3 11.2 — — 31.5 Other income, net — — — 0.5 0.5 EBITDA $ 243.1 $ 77.1 $ (79.6 ) $ (87.7 ) $ 152.9 Purchases of property, plant and equipment $ 76.6 $ 3.3 $ 19.1 $ 1.7 $ 100.7 Crestwood Midstream Year Ended December 31, 2018 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Corporate Total Revenues $ 946.7 $ 17.1 $ 2,690.3 $ — $ 3,654.1 Intersegment revenues 192.4 10.5 (202.9 ) — — Costs of product/services sold 767.0 0.2 2,362.2 — 3,129.4 Operations and maintenance expense 71.7 3.3 50.8 — 125.8 General and administrative expense — — — 83.5 83.5 Gain (loss) on long-lived assets, net (3.0 ) — (27.3 ) 1.7 (28.6 ) Earnings from unconsolidated affiliates, net 22.5 30.8 — — 53.3 EBITDA $ 319.9 $ 54.9 $ 47.1 $ (81.8 ) $ 340.1 Goodwill $ 45.9 $ — $ 92.7 $ — $ 138.6 Total assets $ 2,807.1 $ 1,004.4 $ 612.5 $ 38.0 $ 4,462.0 Purchases of property, plant and equipment $ 294.7 $ 0.6 $ 5.6 $ 4.6 $ 305.5 Year Ended December 31, 2017 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Corporate Total Revenues $ 1,688.2 $ 37.2 $ 2,155.5 $ — $ 3,880.9 Intersegment revenues 134.5 6.7 (141.2 ) — — Costs of product/services sold 1,480.8 0.3 1,893.6 — 3,374.7 Operations and maintenance expense 68.4 4.2 63.4 — 136.0 General and administrative expense — — — 93.1 93.1 Loss on long-lived assets, net (14.4 ) — (48.2 ) (3.0 ) (65.6 ) Goodwill impairment — — (38.8 ) — (38.8 ) Loss on contingent consideration — (57.0 ) — — (57.0 ) Earnings from unconsolidated affiliates, net 18.9 28.9 — — 47.8 Other income, net 0.8 — — — 0.8 EBITDA $ 278.8 $ 11.3 $ (29.7 ) $ (96.1 ) $ 164.3 Goodwill $ 45.9 $ — $ 101.7 $ — $ 147.6 Total assets $ 2,662.0 $ 1,040.6 $ 757.1 $ 6.6 $ 4,466.3 Purchases of property, plant and equipment $ 162.7 $ 1.3 $ 17.7 $ 6.7 $ 188.4 Year Ended December 31, 2016 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Corporate Total Revenues $ 1,118.8 $ 165.3 $ 1,236.4 $ — $ 2,520.5 Intersegment revenues 108.6 4.2 (112.8 ) — — Costs of product/services sold 917.0 5.1 1,003.0 — 1,925.1 Operations and maintenance expense 77.0 18.3 59.7 — 155.0 General and administrative expense — — — 85.6 85.6 Loss on long-lived assets, net (2.0 ) (32.2 ) (31.4 ) — (65.6 ) Goodwill impairment (8.6 ) (44.9 ) (109.1 ) — (162.6 ) Earnings from unconsolidated affiliates, net 20.3 11.2 — — 31.5 EBITDA $ 243.1 $ 80.2 $ (79.6 ) $ (85.6 ) $ 158.1 Purchases of property, plant and equipment $ 76.6 $ 3.3 $ 19.1 $ 1.7 $ 100.7 In conjunction with the adoption of the provisions of Topic 606 , we began reporting our revenues from contracts with customers disaggregated by type of product/service sold and by commodity type for each of our segments for the year ended December 31, 2018 as we believe it best depicts how the nature, amount, timing and uncertainty of our revenues and cash flows are affected by economic factors. See details in the table below for disaggregation of our revenues (in millions) . Year Ended December 31, 2018 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Intersegment Elimination Total Revenues: Topic 606 revenues Gathering Natural gas $ 134.9 $ — $ — $ — $ 134.9 Crude oil 38.8 — — — 38.8 Water 58.0 — — — 58.0 Processing Natural gas 10.7 — — — 10.7 NGLs — — 6.1 — 6.1 Compression Natural gas 29.1 — — — 29.1 Storage Crude oil 1.8 4.2 — (1.5 ) 4.5 NGLs — — 8.6 — 8.6 Pipeline Crude oil — 7.1 — (2.3 ) 4.8 Transportation Crude oil 2.9 — 5.9 — 8.8 NGLs — — 26.9 — 26.9 Water — — 0.3 — 0.3 Rail Loading Crude oil — 14.3 0.2 (5.2 ) 9.3 NGLs — — 3.1 — 3.1 Product Sales Natural gas 55.8 — 70.9 (16.6 ) 110.1 Crude oil 722.9 — 978.0 (151.3 ) 1,549.6 NGLs 84.2 — 1,247.0 (24.5 ) 1,306.7 Other — 2.0 — (1.5 ) 0.5 Total Topic 606 revenues 1,139.1 27.6 2,347.0 (202.9 ) 3,310.8 Non-Topic 606 revenues (1) — — 343.3 — 343.3 Total revenues $ 1,139.1 $ 27.6 $ 2,690.3 $ (202.9 ) $ 3,654.1 (1) Represents revenues related to our commodity-based derivatives. See Note 7 for additional information related to our price risk management activities. Major Customers No customer accounted for 10% or more of our total consolidated revenues for the years ended December 31, 2018 , 2017 or 2016 at CEQP or CMLP.

Condensed Consolidating Financi

Condensed Consolidating Financial Information	12 Months Ended
	Dec. 31, 2018
Condensed Financial Information Disclosure [Abstract]
Condensed Consolidating Financial Information Disclosure	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 Northeast, PRBIC and Tres Holdings and their respective subsidiaries (collectively, Non-Guarantor Subsidiaries). Crestwood Midstream Finance Corp., the co-issuer of its 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 and for the years ended December 31, 2018 , 2017 and 2016 . 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 December 31, 2018 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Assets Current assets: Cash $ 0.2 $ — $ — $ — $ 0.2 Restricted cash 16.3 — — — 16.3 Accounts receivable — 246.3 19.9 (16.3 ) 249.9 Inventory — 64.6 — — 64.6 Other current assets — 46.0 — — 46.0 Total current assets 16.5 356.9 19.9 (16.3 ) 377.0 Property, plant and equipment, net — 2,202.3 — — 2,202.3 Goodwill and intangible assets, net — 692.4 — — 692.4 Investments in consolidated affiliates 3,800.4 — — (3,800.4 ) — Investments in unconsolidated affiliates — — 1,188.2 — 1,188.2 Other non-current assets — 2.1 — — 2.1 Total assets $ 3,816.9 $ 3,253.7 $ 1,208.1 $ (3,816.7 ) $ 4,462.0 Liabilities and partners’ capital Current liabilities: Accounts payable $ 16.3 $ 210.5 $ — $ (16.3 ) $ 210.5 Other current liabilities 20.0 81.8 16.2 — 118.0 Total current liabilities 36.3 292.3 16.2 (16.3 ) 328.5 Long-term liabilities: Long-term debt, less current portion 1,752.4 — — — 1,752.4 Other long-term liabilities — 114.0 57.0 — 171.0 Deferred income taxes — 0.6 — — 0.6 Partners’ capital 2,028.2 2,846.8 953.6 (3,800.4 ) 2,028.2 Interest of non-controlling partner in subsidiary — — 181.3 — 181.3 Total partners’ capital 2,028.2 2,846.8 1,134.9 (3,800.4 ) 2,209.5 Total liabilities and partners’ capital $ 3,816.9 $ 3,253.7 $ 1,208.1 $ (3,816.7 ) $ 4,462.0 Crestwood Midstream Partners LP Condensed Consolidating Balance Sheet December 31, 2017 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Assets Current assets: Cash $ 1.0 $ — $ — $ — $ 1.0 Accounts receivable — 439.7 2.9 — 442.6 Inventory — 68.4 — — 68.4 Other current assets — 18.1 — — 18.1 Total current assets 1.0 526.2 2.9 — 530.1 Property, plant and equipment, net — 2,007.5 — — 2,007.5 Goodwill and intangible assets, net — 743.3 — — 743.3 Investments in consolidated affiliates 3,705.4 — — (3,705.4 ) — Investments in unconsolidated affiliates — — 1,183.0 — 1,183.0 Other non-current assets — 2.4 — — 2.4 Total assets $ 3,706.4 $ 3,279.4 $ 1,185.9 $ (3,705.4 ) $ 4,466.3 Liabilities and partners’ capital Current liabilities: Accounts payable $ — $ 346.8 $ — $ — $ 346.8 Other current liabilities 20.5 134.0 — — 154.5 Total current liabilities 20.5 480.8 — — 501.3 Long-term liabilities: Long-term debt, less current portion 1,490.5 0.8 — — 1,491.3 Other long-term liabilities — 45.6 57.0 — 102.6 Deferred income taxes — 0.7 — — 0.7 Partners’ capital 2,195.4 2,751.5 953.9 (3,705.4 ) 2,195.4 Interest of non-controlling partner in subsidiary — — 175.0 — 175.0 Total partners’ capital 2,195.4 2,751.5 1,128.9 (3,705.4 ) 2,370.4 Total liabilities and partners’ capital $ 3,706.4 $ 3,279.4 $ 1,185.9 $ (3,705.4 ) $ 4,466.3 Crestwood Midstream Partners LP Condensed Consolidating Statements of Operations Year Ended December 31, 2018 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Revenues $ — $ 3,654.1 $ — $ — $ 3,654.1 Costs of product/services sold — 3,129.4 — — 3,129.4 Operating expenses and other: Operations and maintenance — 125.8 — — 125.8 General and administrative 55.1 28.4 — — 83.5 Depreciation, amortization and accretion — 181.4 — — 181.4 Loss on long-lived assets, net — 28.6 — — 28.6 55.1 364.2 — — 419.3 Operating income (loss) (55.1 ) 160.5 — — 105.4 Earnings from unconsolidated affiliates, net — — 53.3 — 53.3 Interest and debt expense, net (99.2 ) — — — (99.2 ) Loss on modification/extinguishment of debt (0.9 ) — — — (0.9 ) Equity in net income (loss) of subsidiaries 197.6 — — (197.6 ) — Net income (loss) 42.4 160.5 53.3 (197.6 ) 58.6 Net income attributable to non-controlling partner — — 16.2 — 16.2 Net income (loss) attributable to Crestwood Midstream Partners LP $ 42.4 $ 160.5 $ 37.1 $ (197.6 ) $ 42.4 Crestwood Midstream Partners LP Condensed Consolidating Statements of Operations Year Ended December 31, 2017 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Revenues $ — $ 3,880.9 $ — $ — $ 3,880.9 Costs of product/services sold — 3,374.7 — — 3,374.7 Operating expenses and other: Operations and maintenance — 136.0 — — 136.0 General and administrative 67.6 25.5 — — 93.1 Depreciation, amortization and accretion — 202.7 — — 202.7 Loss on long-lived assets, net — 65.6 — — 65.6 Goodwill impairment — 38.8 — — 38.8 Loss on contingent consideration — — 57.0 — 57.0 67.6 468.6 57.0 — 593.2 Operating income (loss) (67.6 ) 37.6 (57.0 ) — (87.0 ) Earnings from unconsolidated affiliates, net — — 47.8 — 47.8 Interest and debt expense, net (99.4 ) — — — (99.4 ) Loss on modification/extinguishment of debt (37.7 ) — — — (37.7 ) Other income, net — 0.8 — — 0.8 Equity in net income (loss) of subsidiaries 3.9 — — (3.9 ) — Net income (loss) (200.8 ) 38.4 (9.2 ) (3.9 ) (175.5 ) Net income attributable to non-controlling partner — — 25.3 — 25.3 Net income (loss) attributable to Crestwood Midstream Partners LP $ (200.8 ) $ 38.4 $ (34.5 ) $ (3.9 ) $ (200.8 ) Crestwood Midstream Partners Condensed Consolidating Statements of Operations Year Ended December 31, 2016 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Revenues $ — $ 2,520.5 $ — $ — $ 2,520.5 Costs of product/services sold — 1,925.1 — — 1,925.1 Operating expenses and other: Operations and maintenance — 155.0 — — 155.0 General and administrative 66.4 19.2 — — 85.6 Depreciation, amortization and accretion — 240.5 — — 240.5 Loss on long-lived assets, net — 65.6 — — 65.6 Goodwill impairment — 162.6 — — 162.6 66.4 642.9 — — 709.3 Operating loss (66.4 ) (47.5 ) — — (113.9 ) Earnings from unconsolidated affiliates, net — — 31.5 — 31.5 Interest and debt expense, net (125.1 ) — — — (125.1 ) Gain on modification/extinguishment of debt 10.0 — — — 10.0 Equity in net income (loss) of subsidiaries (40.2 ) — — 40.2 — Net income (loss) (221.7 ) (47.5 ) 31.5 40.2 (197.5 ) Net income attributable to non-controlling partner — — 24.2 — 24.2 Net income (loss) attributable to Crestwood Midstream Partners LP $ (221.7 ) $ (47.5 ) $ 7.3 $ 40.2 $ (221.7 ) Crestwood Midstream Partners LP Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2018 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Cash flows from operating activities: $ (131.7 ) $ 339.2 $ 53.0 $ — $ 260.5 Cash flows from investing activities: Purchases of property, plant and equipment — (305.5 ) — — (305.5 ) Investment in unconsolidated affiliates — — (64.4 ) — (64.4 ) Capital distributions from unconsolidated affiliates — — 49.2 — 49.2 Net proceeds from sale of assets — 79.5 — — 79.5 Capital distributions from consolidated affiliates 27.9 — — (27.9 ) — Net cash provided by (used in) investing activities 27.9 (226.0 ) (15.2 ) (27.9 ) (241.2 ) Cash flows from financing activities: Proceeds from the issuance of long-term debt 2,274.8 — — — 2,274.8 Payments on long-term debt (2,014.8 ) (0.9 ) — — (2,015.7 ) Payments on capital leases — (1.6 ) — — (1.6 ) Payments for debt-related deferred costs (5.7 ) — — — (5.7 ) Distributions to partners (238.4 ) — (9.9 ) — (248.3 ) Distributions to parent — — (27.9 ) 27.9 — Taxes paid for unit-based compensation vesting — (7.4 ) — — (7.4 ) Change in intercompany balances 103.4 (103.4 ) — — — Other — 0.1 — — 0.1 Net cash provided by (used in) financing activities 119.3 (113.2 ) (37.8 ) 27.9 (3.8 ) Net change in cash and restricted cash 15.5 — — — 15.5 Cash and restricted cash at beginning of period 1.0 — — — 1.0 Cash and restricted cash at end of period $ 16.5 $ — $ — $ — $ 16.5 Crestwood Midstream Partners LP Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2017 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Cash flows from operating activities: $ (162.3 ) $ 379.2 $ 45.3 $ — $ 262.2 Cash flows from investing activities: Purchases of property, plant and equipment — (188.4 ) — — (188.4 ) Investment in unconsolidated affiliates — — (58.0 ) — (58.0 ) Capital distributions from unconsolidated affiliates — — 59.9 — 59.9 Net proceeds from sale of assets — 225.2 — — 225.2 Capital distributions from consolidated affiliates 4.3 — — (4.3 ) — Net cash provided by (used in) investing activities 4.3 36.8 1.9 (4.3 ) 38.7 Cash flows from financing activities: Proceeds from the issuance of long-term debt 2,838.6 — — — 2,838.6 Payments on long-term debt (2,912.6 ) (1.3 ) — — (2,913.9 ) Payments on capital leases — (2.7 ) — — (2.7 ) Payments for deferred financing costs (1.0 ) — — — (1.0 ) Redemption of non-controlling interest — — (202.7 ) — (202.7 ) Net proceeds from issuance of non-controlling interest — — 175.0 — 175.0 Distributions to partners (174.0 ) — (15.2 ) — (189.2 ) Distributions to parent — — (4.3 ) 4.3 — Taxes paid for unit-based compensation vesting — (5.5 ) — — (5.5 ) Change in intercompany balances 406.7 (406.7 ) — — — Other — 0.2 — — 0.2 Net cash provided by (used in) financing activities 157.7 (416.0 ) (47.2 ) 4.3 (301.2 ) Net change in cash and restricted cash (0.3 ) — — — (0.3 ) Cash and restricted cash at beginning of period 1.3 — — — 1.3 Cash and restricted cash at end of period $ 1.0 $ — $ — $ — $ 1.0 Crestwood Midstream Partners LP Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2016 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Cash flows from operating activities: $ (188.0 ) $ 502.8 $ 39.0 $ — $ 353.8 Cash flows from investing activities: Acquisitions, net of cash acquired — (7.2 ) — — (7.2 ) Purchases of property, plant and equipment — (100.7 ) — — (100.7 ) Investment in unconsolidated affiliates — — (12.4 ) — (12.4 ) Capital distributions from unconsolidated affiliates — — 14.8 — 14.8 Net proceeds from sale of assets — 972.7 — — 972.7 Capital contributions to consolidated affiliates 26.2 — — (26.2 ) — Net cash provided by (used in) investing activities 26.2 864.8 2.4 (26.2 ) 867.2 Cash flows from financing activities: Proceeds from the issuance of long-term debt 1,565.3 — — — 1,565.3 Payments on long-term debt (2,535.3 ) (0.8 ) — — (2,536.1 ) Payments on capital leases — (1.9 ) — — (1.9 ) Payments for deferred financing costs (3.5 ) — — — (3.5 ) Distributions to partners (227.6 ) — (15.2 ) — (242.8 ) Distributions to parent — — (26.2 ) 26.2 — Taxes paid for unit-based compensation vesting — (0.8 ) — — (0.8 ) Change in intercompany balances 1,364.1 (1,364.1 ) — — — Net cash provided by (used in) financing activities 163.0 (1,367.6 ) (41.4 ) 26.2 (1,219.8 ) Net change in cash and restricted cash 1.2 — — — 1.2 Cash and restricted cash at beginning of period 0.1 — — — 0.1 Cash and restricted cash at end of period $ 1.3 $ — $ — $ — $ 1.3

Schedule I - Crestwood Equity P

Schedule I - Crestwood Equity Partners LP - Parent Only	12 Months Ended
	Dec. 31, 2018
Condensed Financial Information Disclosure [Abstract]
Schedule I - Crestwood Equity Partners LP - Parent Only	Schedule I Crestwood Equity Partners LP Parent Only Condensed Balance Sheets (in millions) December 31, 2018 2017 Assets Current assets: Cash $ 0.2 $ 0.3 Total current assets 0.2 0.3 Property, plant and equipment, net 1.1 1.2 Intangible assets, net — 1.4 Investments in subsidiaries 1,854.7 2,005.1 Other assets 2.8 3.5 Total assets $ 1,858.8 $ 2,011.5 Liabilities and partners’ capital Current liabilities: Accounts payable $ 2.6 $ 2.7 Accrued expenses 1.1 1.2 Total current liabilities 3.7 3.9 Other long-term liabilities 2.6 2.1 Total partners’ capital 1,852.5 2,005.5 Total liabilities and partners’ capital $ 1,858.8 $ 2,011.5 See accompanying notes. Schedule I Crestwood Equity Partners LP Parent Only Condensed Statements of Operations (in millions) Year Ended December 31, 2018 2017 2016 Revenues $ — $ — $ — Expenses 6.1 6.7 6.0 Operating loss (6.1 ) (6.7 ) (6.0 ) Equity in net income (loss) of subsidiaries 72.7 (160.4 ) (186.6 ) Other income, net 0.4 0.5 0.5 Net income (loss) 67.0 (166.6 ) (192.1 ) Net income attributable to non-controlling partners 16.2 25.3 24.2 Net income (loss) attributable to Crestwood Equity Partners LP $ 50.8 $ (191.9 ) $ (216.3 ) See accompanying notes. Schedule I Crestwood Equity Partners LP Parent Only Condensed Statements of Comprehensive Income (in millions) Year Ended December 31, 2018 2017 2016 Net income (loss) $ 67.0 $ (166.6 ) $ (192.1 ) Change in fair value of Suburban Propane Partners, LP units (0.7 ) (0.8 ) 0.8 Comprehensive income (loss) 66.3 (167.4 ) (191.3 ) Comprehensive income attributable to non-controlling interest 16.2 25.3 24.2 Comprehensive income (loss) attributable to Crestwood Equity Partners LP $ 50.1 $ (192.7 ) $ (215.5 ) See accompanying notes. Schedule I Crestwood Equity Partners LP Parent Only Condensed Statements of Cash Flows (in millions) Year Ended December 31, 2018 2017 2016 Cash flows from operating activities $ (3.8 ) $ (3.6 ) $ (3.5 ) Cash flows from investing activities 238.4 174.0 227.6 Cash flows from financing activities: Principal payments on long-term debt — — (0.2 ) Distributions paid to partners (230.9 ) (182.6 ) (219.8 ) Proceeds from issuance of common units — 15.2 — Change in intercompany balances (3.8 ) (3.0 ) (4.2 ) Net cash used in financing activities (234.7 ) (170.4 ) (224.2 ) Net change in cash (0.1 ) — (0.1 ) Cash at beginning of period 0.3 0.3 0.4 Cash at end of period $ 0.2 $ 0.3 $ 0.3 See accompanying notes. Schedule I Crestwood Equity Partners LP Parent Only Notes to Condensed Financial Statements Note 1. Basis of Presentation In the parent-only financial statements, our investment in subsidiaries is stated at cost plus equity in undistributed earnings of subsidiaries since the date of acquisition. Our share of net income of our unconsolidated subsidiaries is included in consolidated income using the equity method. The parent-only financial statements should be read in conjunction with our consolidated financial statements. Note 2. Distributions During the years ended December 31, 2018 , 2017 and 2016 , we received cash distributions from Crestwood Midstream Partners LP of approximately $238.4 million , $174.0 million and $227.6 million .

Schedule II - Crestwood Equity

Schedule II - Crestwood Equity Parnters LP - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2018
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
Schedule II - Crestwood Equity Parnters LP - Valuation and Qualifying Accounts	Schedule II Crestwood Equity Partners LP Crestwood Midstream Partners LP Valuation and Qualifying Accounts For the Years Ended December 31, 2018 , 2017 and 2016 (in millions) Balance at beginning of period Charged to costs and expenses Other Additions Deductions (write-offs) Balance at end of period Allowance for doubtful accounts 2018 $ 2.4 $ 0.2 $ — $ (2.3 ) $ 0.3 2017 1.9 1.5 — (1.0 ) 2.4 2016 0.4 1.9 — (0.4 ) 1.9

Basis of Presentation and Sum_2

Basis of Presentation and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Use of Estimates	Use of Estimates The preparation of our consolidated financial statements in conformity with GAAP requires the use of estimates and assumptions that affect the amounts we report as assets, liabilities, revenues and expenses and our disclosures in these consolidated financial statements. Actual results can differ from those estimates.
Cash and Restricted Cash	Cash We consider all highly liquid investments with an original maturity of less than three months to be cash. Restricted Cash On January 1, 2018, we adopted the provisions of ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force) which changed the classification and presentation of restricted cash in the statement of cash flows. The standard requires us to include restricted cash in our total cash when reconciling the beginning of period and end of period amounts shown on our consolidated statements of cash flows. The retrospective application of this ASU did not have an impact on our consolidated statements of cash flows for the years ended December 31, 2017 and 2016. Our restricted cash represents cash held under the terms of certain contractual agreements and is classified as current on our consolidated balance sheets. The change in restricted cash for the year ended December 31, 2018 is approximately $16.3 million and is included in operating activities (change in accounts payable, accrued expenses and other liabilities) in the consolidated statements of cash flows.
Inventory	Inventory Inventory for our marketing, supply and logistics operations are stated at the lower of cost or net realizable value and cost is computed predominantly using the average cost method.
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment is recorded at is original cost of construction or, upon acquisition, at the fair value of the assets acquired. For assets we construct, we capitalize direct costs, such as labor and materials, and indirect costs, such as overhead and interest. We capitalize major units of property replacements or improvement and expense minor items. Depreciation is computed by the straight-line method over the estimated useful lives of the assets, as follows: Years Gathering systems and pipelines 15 - 20 Facilities and equipment 3 - 25 Buildings, rights-of-way and easements 1 - 40 Office furniture and fixtures 5 - 10 Vehicles 5 We depleted salt deposits included in our property, plant and equipment utilizing the unit of production method prior to their sale in December 2017. We evaluate our long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If such events or changes in circumstances are present, a loss is recognized if the carrying value of the asset is in excess of the sum of the undiscounted cash flows expected to result from the use of the asset and its eventual disposition. An impairment loss is measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset, which is typically based on discounted cash flow projections using assumptions as to revenues, costs and discount rates typical of third party market participants, which is a Level 3 fair value measurement. We did not record impairments of our property, plant and equipment during the year ended December 31, 2018 and 2016 . During 2017, we incurred $81.4 million of impairments of our property, plant and equipment related to our MS&L West Coast operations, which resulted from decreasing the forecasted cash flows to be generated by those operations. At December 31, 2017 , our estimates of fair value considered a number of factors, including the potential value if we sold the asset, a 12% discount rate and projected cash flows, which is a Level 3 fair value measurement. During 2018, we sold our MS&L West Coast operations for $70.5 million , and recorded a loss on long-lived assets of approximately $26.9 million (including $9.0 million related to the write off of goodwill). See “ Goodwill ” below and Note 3 for further information on the sale of these assets. Projected cash flows of our property, plant and equipment are generally based on current and anticipated future market conditions, which require significant judgment to make projections and assumptions about pricing, demand, competition, operating costs, constructions costs, legal and regulatory issues and other factors that may extend many years into the future and are often outside of our control. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates.
Identifiable Intangible Assets	Identifiable Intangible Assets Our identifiable intangible assets consist of customer accounts, covenants not to compete, trademarks and certain revenue contracts. Customer accounts, covenants not to compete, trademarks and certain of our revenue contracts have arisen from acquisitions. We amortize certain of our revenue contracts based on the projected cash flows associated with these contracts if the projected cash flows are readily determinable, otherwise we amortize our revenue contracts on a straight-line basis. We recognize acquired intangible assets separately if the benefit of the intangible asset is obtained through contractual or other legal rights, or if the intangible asset can be sold, transferred, licensed, rented or exchanged, regardless of the acquirer’s intent to do so.
Goodwill	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. We also compare the total fair value of our reporting units to our overall enterprise value, which considers the market value for our common and preferred units. 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.
Investment in Unconsolidated Affiliate	Investments in Unconsolidated Affiliates Equity method investments in which we exercise significant influence, but do not control and are not the primary beneficiary, are accounted for using the equity method of accounting. Differences in the basis of investments and the separate net asset values of the investees, if any, are amortized into net income or loss over the remaining useful lives of the underlying assets and liabilities, except for the excess related to goodwill. 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, or if we decide to sell an investment in unconsolidated affiliate, we adjust the carrying values of the asset downward, if necessary, to their estimated fair values.
Asset Retirement Obligations	Asset Retirement Obligations An asset retirement obligation (ARO) is an estimated liability for the cost to retire a tangible asset. We record a liability for legal or contractual obligations to retire our long-lived assets associated with our facilities and right-of-way contracts we hold. We record a liability in the period the obligation is incurred and estimable. An ARO is initially recorded at its estimated fair value with a corresponding increase to property, plant and equipment. This increase in property, plant and equipment is then depreciated over the useful life of the asset to which that liability relates. An ongoing expense is recognized for changes in the fair value of the liability as a result of the passage of time, which we record as depreciation, amortization and accretion expense on our consolidated statements of operations. We have various obligations to remove property, plant and equipment on rights-of-way and leases for which we cannot currently estimate the fair value of those obligations because the associated assets have indeterminate lives. An asset retirement obligation liability (and related assets), if any, will be recorded for these obligations once sufficient information is available to reasonably estimate the fair value of the obligations.
Revenue Recognition	Revenue Recognition We provide gathering, processing, compression, storage, fractionation, and transportation (consisting of pipelines, truck and rail terminals, truck/trailer units and rail cars) services and we sell commodities (including crude oil, natural gas, NGLs and water) under various contracts. These contracts include: • Fixed-fee contracts . Under these contracts, we do not take title to the underlying crude oil, natural gas or NGLs but charge our customers a fixed-fee for the services we provide, which can be a firm reservation charge and/or a charge per volume gathered, processed, compressed, stored, loaded and/or transported (which, in certain contracts, can be subject to a minimum level of volumes); • Percentage-of-proceeds service contracts . Under these contracts, we take title to crude oil, natural gas or NGLs after the commodity leaves our gathering and processing facilities. We often market and sell those commodities to third parties after they leave our facilities and we will remit a portion of the sales proceeds to our producers; • Percentage-of-proceeds product contracts. Under these contracts, we take title to crude oil, natural gas or NGLs before the commodity enters our facilities. We market and sell those commodities to third parties and we will remit a portion of the sales proceeds to our producers; and • Purchase and sale contracts . Under these contracts, we purchase crude oil, natural gas or NGLs before the commodity enters our facilities, and we market and sell those commodities to third parties. On January 1, 2018, we adopted the provisions of ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers. We adopted the standard using the modified retrospective method for all revenue contracts that involve revenue generating activities that occur after January 1, 2018. Results for reporting periods beginning after January 1, 2018 are presented under the new standard, while amounts prior to January 1, 2018 continue to be reported in accordance with our historic accounting under Revenue Recognition (Topic 605) . Prior to January 1, 2018, we recognized revenues for services and products when all of the following criteria were met under Topic 605 : (i) services had been rendered or products delivered or sold; (ii) persuasive evidence of an exchange arrangement existed; (iii) the price for services was fixed or determinable; and (iv) collectability was reasonably assured. We recorded deferred revenue when we received amounts from our customers but had not yet met the criteria listed above. We recognized deferred revenue in our consolidated statement of operations when the criteria had been met and all services had been rendered. At December 31, 2017, we had deferred revenue of approximately $0.6 million , which is reflected in accrued expenses and other liabilities on our consolidated balance sheet. Beginning January 1, 2018, we recognize revenues for services and products under revenue contracts as our obligations to perform services or deliver/sell products under the contracts are satisfied. A contract’s transaction price is allocated to each performance obligation in the contract and recognized as revenue when, or as, the performance obligation is satisfied. Our fixed-fee contracts and our percentage-of-proceeds service contracts primarily have a single performance obligation to deliver a series of distinct goods or services that are substantially the same and have the same pattern of transfer to our customers. For performance obligations associated with these contracts, we recognize revenues over time utilizing the output method based on the actual volumes of products delivered/sold or services performed, because the single performance obligation is satisfied over time using the same performance measure of progress toward satisfaction of the performance obligation . The transaction price under certain of our fixed-price contracts and percentage-of-proceeds service contracts includes variable consideration that varies primarily based on actual volumes that are delivered under the contracts. Because the variable consideration specifically relates to our efforts to transfer the services and/or products under the contracts, we allocate the variable consideration entirely to the distinct service utilizing the allocation exception guidance under Topic 606 , and accordingly recognize the variable consideration as revenues at the time the good or service is transferred to the customer. Certain of our fixed-fee contracts contain minimum volume features under which the customers must utilize our services to gather, compress or load a specified quantity of crude oil or natural gas or pay a deficiency fee based on the difference between actual volumes and the contractual minimum volume. We recognize revenues from these contracts when actual volumes are gathered, compressed or loaded and the likelihood of a customer exercising its remaining rights to make up the deficient volumes under minimum volume commitments becomes remote. We recognize revenues at a point in time for performance obligations associated with our percentage-of proceeds product contracts and purchase and sale contracts, and these revenues are recognized because control of the underlying product is transferred to the customer when the distinct good is provided to the customer. The evaluation of when performance obligations have been satisfied and the transaction price that is allocated to our performance obligations requires significant judgments and assumptions, including our evaluation of the timing of when control of the underlying good or service has transferred to our customers and the relative standalone selling price of goods and services provided to customers under contracts with multiple performance obligations. Actual results can significantly vary from those judgments and assumptions. We did not have any material contracts with multiple performance obligations or under which we receive material amounts of non-cash consideration during the year ended December 31, 2018 . The following table summarizes the transaction price allocated to our remaining performance obligations under certain contracts that have not been recognized as of December 31, 2018 (in millions) : 2019 $ 32.5 2020 23.5 2021 9.4 2022 7.3 2023 7.3 Thereafter 3.3 Total $ 83.3 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. Contract Assets and Contract Liabilities . Amounts due from our customers under our revenue contracts are typically billed as the service is being provided or on a weekly, bi-weekly or monthly basis and are due within 30 days of billing. Under certain of our contracts, we recognize revenues in excess of billings which we present as contract assets on our consolidated balance sheets. Under certain contracts, we may be entitled to receive payments in advance of satisfying our performance obligations under the contract. We recognize a liability for these payments in excess of revenue recognized and present it as deferred revenue or contract liabilities on our consolidated balance sheets. Our deferred revenue primarily relates to: • Capital Reimbursements. Certain contracts in our G&P segment require that our customers reimburse us for capital expenditures related to the construction of long-lived assets utilized to provide services to them under the revenue contracts. Because we consider these amounts as consideration from customers associated with ongoing services to be provided to customers, we defer these upfront payments in deferred revenue and recognize the amounts in revenue over the life of the associated revenue contract as the performance obligations are satisfied under the contract. On January 1, 2018, we recorded an $87.6 million increase to our property, plant and equipment, net, a $69.1 million increase to our deferred revenue liability and an $18.5 million increase to partners’ capital as a result of applying the cumulative impact of adopting the new standard on these types of contracts. • Contracts with Increasing (Decreasing) Rates per Unit. Certain contracts in our G&P, S&T and MS&L segments have fixed rates per volume that increase and/or decrease over the life of the contract once certain time periods or thresholds are met. We record revenues on these contracts ratably per unit over the life of the contract based on the remaining performance obligations to be performed, which can result in the deferral of revenue for the difference between the consideration received and the ratable revenue recognized. On January 1, 2018, we recorded a $1.5 million increase to our deferred revenue liability and a corresponding decrease to partners’ capital as a result of applying the cumulative impact of adopting the new standard on these types of contracts. 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 Topic 606 revenue contracts totaled $209.7 million for both CEQP and CMLP at December 31, 2018 , and are included in accounts receivable on our consolidated balance sheet. Our contract assets are included in other non-current assets on our consolidated balance sheet. 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 revenue contracts are satisfied over the next 13 years .
Credit Risk and Concentrations	Credit Risk and Concentrations Inherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate.
Income Taxes	Income Taxes Crestwood Equity is a master limited partnership and Crestwood Midstream is a limited partnership. Partnerships are generally not subject to federal income tax, although publicly-traded partnerships are treated as corporations for federal income tax purposes and therefore are subject to federal income tax, unless the partnership generates at least 90% of its gross income from qualifying sources. If the qualifying income requirement is satisfied, the publicly-traded partnership will be treated as a partnership for federal income tax purposes. We satisfy the qualifying income requirement and are treated as a partnership for federal and state income tax purposes. Our consolidated earnings are included in the federal and state income tax returns of our partners. However, legislation in certain states allows for taxation of partnerships, and as such, certain state taxes have been included in our accompanying financial statements as income taxes due to the nature of the tax in those particular states as discussed below. In addition, federal and state income taxes are provided on the earnings of the subsidiaries incorporated as taxable entities. We are required to recognize deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements or tax returns. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial reporting and tax basis of assets and liabilities using expected rates in effect for the year in which the differences are expected to reverse. We are responsible for the Texas Margin tax computed on the Texas franchise tax returns. The margin tax qualifies as an income tax under GAAP, which requires us to recognize the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis attributable to such tax. Net earnings for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax basis and the financial reporting basis of assets and liabilities and the taxable income allocation requirements under the partnership agreement.
Environmental Costs and Other Contingencies	Environmental Costs and Other Contingencies We recognize liabilities for environmental and other contingencies when there is an exposure that indicates it is both probable that a liability has been incurred and the amount of loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue a liability for that amount. Where the most likely outcome cannot be estimated, a range of potential losses is established and if no one amount in that range is more likely than any other, the low end of range is accrued. We record liabilities for environmental contingencies at their undiscounted amounts on our consolidated balance sheets as accrued expenses and other liabilities when environmental assessments indicate that remediation efforts are probable and costs can be reasonably estimated. Estimates of our liabilities are based on currently available facts and presently enacted laws and regulations, taking into consideration the likely effects of other societal and economic factors. These estimates are subject to revision in future periods based on actual costs or new circumstances. We capitalize costs that benefit future periods and recognize a current period charge in operations and maintenance expenses when clean-up efforts do not benefit future periods. We evaluate potential recoveries of amounts from third parties, including insurance coverage, separately from our liability. Recovery is evaluated based on the solvency of the third party, among other factors. When recovery is assured, we record and report an asset separately from the associated liability on our consolidated balance sheet.
Price Risk Management Activities	Price Risk Management Activities We utilize certain derivative financial instruments to (i) manage our exposure to commodity price risk, specifically, the related change in the fair value of inventory, as well as the variability of cash flows related to forecasted transactions; (ii) ensure the availability of adequate physical supply of commodity; and (iii) manage our exposure to the interest rate risk associated with fixed and variable rate borrowings. We record all derivative instruments on the balance sheet at their fair values as either assets or liabilities measured at fair value. Changes in the fair value of these derivative financial instruments are recorded through current earnings.
Unit-Based Compensation	Unit-Based Compensation Long-term incentive awards are granted under the Crestwood Equity incentive plan. Unit-based compensation awards consist of restricted units that are valued at the closing market price of CEQP’s common units on the date of grant, which reflects the fair value of such awards. For those awards that are settled in cash, the associated liability is remeasured at every balance sheet date through settlement, such that the vested portion of the liability is adjusted to reflect its revised fair value through compensation expense. We generally recognize the expense associated with the award over the vesting period on a straight line basis. Effective January 1, 2017, we adopted the provisions of ASU 2016-09, Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting , which simplifies several aspects of the accounting for share-based payment award transactions, including the classification of awards as either equity or liabilities and the presentation on the statement of cash flows. The adoption of this accounting standard did not have a material impact on our consolidated financial statements.

Basis of Presentation and Sum_3

Basis of Presentation and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Estimated Useful Lives Of Property, Plant And Equipment	Depreciation is computed by the straight-line method over the estimated useful lives of the assets, as follows: Years Gathering systems and pipelines 15 - 20 Facilities and equipment 3 - 25 Buildings, rights-of-way and easements 1 - 40 Office furniture and fixtures 5 - 10 Vehicles 5
Intangible Assets, Useful life	Certain intangible assets are amortized on a straight-line basis over their estimated economic lives, as follows: Weighted-Average Life (years) Customer accounts and revenue contracts 20 Trademarks 10 Intangible assets consisted of the following at December 31, 2018 and 2017 ( in millions ): CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Customer accounts $ 438.9 $ 438.9 $ 438.9 $ 438.9 Gas gathering, compression and processing contracts 325.2 325.2 325.2 325.2 Trademarks (1) 6.2 24.7 6.2 9.2 770.3 788.8 770.3 773.3 Less: accumulated amortization 216.5 191.6 216.5 177.6 Total intangible assets, net $ 553.8 $ 597.2 $ 553.8 $ 595.7 (1) As of December 31, 2018, we fully amortized and eliminated certain intangibles associated with our trademarks. The following table summarizes total accumulated amortization of our intangible assets at December 31, 2018 and 2017 ( in millions ): CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Customer accounts $ 112.1 $ 89.8 $ 112.1 $ 89.8 Gas gathering, compression and processing contracts 100.8 82.0 100.8 82.0 Trademarks 3.6 19.8 3.6 5.8 Total accumulated amortization $ 216.5 $ 191.6 $ 216.5 $ 177.6
Schedule of Goodwill	The following table summarizes the goodwill of our various reporting units ( in millions ): Goodwill Impairments during the Year Ended December 31, 2016 Goodwill at January 1, 2017 Impact of Sale of US Salt Goodwill Impairments during the Year Ended December 31, 2017 Goodwill at December 31, 2017 Other Impact of Sale of West Coast Goodwill at December 31, 2018 G&P Marcellus $ 8.6 $ — $ — $ — $ — $ — $ — $ — Arrow — 45.9 — — 45.9 — — 45.9 S&T COLT 44.9 — — — — — — — MS&L NGL Marketing and Logistics — — — — — 101.7 (2) (9.0 ) (1) 92.7 West Coast — 2.4 — 2.4 — — — — Supply and Logistics 65.5 101.7 — — 101.7 (101.7 ) (2) — — Storage and Terminals 14.1 36.4 — 36.4 — — — — US Salt — 12.6 (12.6 ) (1) — — — — — Trucking 29.5 — — — — — — — Total $ 162.6 $ 199.0 $ (12.6 ) $ 38.8 $ 147.6 $ — $ (9.0 ) $ 138.6 (1) In December 2017, we sold 100% of our equity interests in US Salt to an affiliate of Kissner Group Holdings LP. In October 2018, we sold our West Coast assets and wrote off the goodwill attributable to these assets as further discussed below. (2) Reflects the combination of the MS&L reporting units into one NGL Marketing and Logistics reporting unit as further discussed below.
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	The following table summarizes the transaction price allocated to our remaining performance obligations under certain contracts that have not been recognized as of December 31, 2018 (in millions) : 2019 $ 32.5 2020 23.5 2021 9.4 2022 7.3 2023 7.3 Thereafter 3.3 Total $ 83.3
Contract with Customer, Asset and Liability	The following table summarizes the opening and closing balances of our contract assets and contract liabilities (in millions) : Balance at January 1, 2018 Balance at December 31, 2018 Contract Assets (Non-current) $ 1.1 $ 1.0 Contract Liabilities (Current) (1) 12.2 12.0 Contract Liabilities (Non-current) (1) 60.6 65.4 (1) During the year ended December 31, 2018 , we recognized revenues of approximately $12.2 million that were previously included in contract liabilities (current) at January 1, 2018. The remaining change in our contract liabilities during the year ended December 31, 2018, primarily related to capital reimbursements associated with our revenue contracts and revenue deferrals associated with our contracts with increasing (decreasing) rates.
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	The adoption of Topic 606 had the following impact on CEQP’s and CMLP’s consolidated income statements and balance sheets (in millions) : Crestwood Equity Year Ended December 31, 2018 As Reported under Topic 606 Prior to Adoption of Topic 606 Increase (Decrease) Income Statement Product revenues: Gathering and processing (1) $ 670.5 $ 1,643.1 $ (972.6 ) Service revenues: Gathering and processing (1)(2) 276.1 318.9 (42.8 ) Marketing, supply and logistics (3) 50.2 49.4 0.8 Costs of product/services sold: Product costs (1) 2,950.5 3,977.3 (1,026.8 ) Depreciation, amortization and accretion (2) 168.7 163.7 5.0 Earnings from unconsolidated affiliates, net (4) 53.3 63.0 (9.7 ) Net income 67.0 69.5 (2.5 ) December 31, 2018 As Reported under Topic 606 Prior to Adoption of Topic 606 Increase (Decrease) Balance Sheet Assets: Property, plant and equipment (2) $ 2,598.1 $ 2,480.1 $ 118.0 Accumulated depreciation and depletion (2) 568.4 551.2 17.2 Investments in unconsolidated affiliates (4) 1,188.2 1,207.4 (19.2 ) Liabilities: Accrued expenses and other liabilities (2)(3) 112.4 101.2 11.2 Other long-term liabilities (2)(3) 173.6 108.2 65.4 Partners’ capital: Crestwood Equity Partners LP partners’ capital (2)(3)(4) 1,240.5 1,235.5 5.0 Crestwood Midstream Year Ended December 31, 2018 As Reported under Topic 606 Prior to Adoption of Topic 606 Increase (Decrease) Income Statement Product revenues: Gathering and processing (1) $ 670.5 $ 1,643.1 $ (972.6 ) Service revenues: Gathering and processing (1)(2) 276.1 318.9 (42.8 ) Marketing, supply and logistics (3) 50.2 49.4 0.8 Costs of product/services sold: Product costs (1) 2,950.5 3,977.3 (1,026.8 ) Depreciation, amortization and accretion (2) 181.4 176.4 5.0 Earnings from unconsolidated affiliates, net (4) 53.3 63.0 (9.7 ) Net income 58.6 61.1 (2.5 ) December 31, 2018 As Reported under Topic 606 Prior to Adoption of Topic 606 Increase (Decrease) Balance Sheet Assets: Property, plant and equipment (2) $ 2,928.2 $ 2,810.2 $ 118.0 Accumulated depreciation and depletion (2) 725.9 708.7 17.2 Investments in unconsolidated affiliates (4) 1,188.2 1,207.4 (19.2 ) Liabilities: Accrued expenses and other liabilities (2)(3) 111.3 100.1 11.2 Other long-term liabilities (2)(3) 171.0 105.6 65.4 Partners’ capital (2)(3)(4) 2,028.2 2,023.2 5.0 (1) On January 1, 2018, we began classifying product and service revenues as a reduction of costs of product sold on certain of our gathering and processing contracts. (2) On January 1, 2018, we began recording proceeds received from customers for reimbursable construction as deferred revenue instead of as reductions of property, plant and equipment. (3) For contracts that have fixed rates per volume that increase and/or decrease over the life of the contract once certain time periods or thresholds have been met, on January 1, 2018, we began recording revenues on those contracts ratably per unit over the life of the contract based on the remaining performance obligations to be performed. (4) On January 1, 2018, Jackalope Gas Gathering Services, L.L.C. (Jackalope) adopted the provisions of Topic 606 , and we recorded a $9.5 million decrease to our equity method 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. In addition, our earnings from unconsolidated affiliates decreased by approximately $9.7 million during the year ended December 31, 2018 to reflect our proportionate share of the ongoing impact of the new standard on Jackalope’s revenues. The adoption of Topic 606 was not material to our other equity method investments.

Certain Balance Sheet Informa_2

Certain Balance Sheet Information (Tables)	12 Months Ended
	Dec. 31, 2018
Balance Sheet Related Disclosures [Abstract]
Property, Plant And Equipment	Property, plant and equipment consisted of the following at December 31, 2018 and 2017 ( in millions ): CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Gathering systems and pipelines and related assets $ 758.6 $ 678.0 $ 901.5 $ 820.9 Facilities and equipment 1,230.7 1,141.4 1,415.9 1,326.5 Buildings, land, rights-of-way, storage rights and easements 331.7 319.1 335.4 322.8 Vehicles 17.9 37.3 16.1 35.5 Construction in process 230.8 87.5 230.8 87.5 Office furniture and fixtures 28.4 21.9 28.5 22.1 2,598.1 2,285.2 2,928.2 2,615.3 Less: accumulated depreciation and depletion 568.4 464.4 725.9 607.8 Total property, plant and equipment, net $ 2,029.7 $ 1,820.8 $ 2,202.3 $ 2,007.5
Intangible Assets	Certain intangible assets are amortized on a straight-line basis over their estimated economic lives, as follows: Weighted-Average Life (years) Customer accounts and revenue contracts 20 Trademarks 10 Intangible assets consisted of the following at December 31, 2018 and 2017 ( in millions ): CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Customer accounts $ 438.9 $ 438.9 $ 438.9 $ 438.9 Gas gathering, compression and processing contracts 325.2 325.2 325.2 325.2 Trademarks (1) 6.2 24.7 6.2 9.2 770.3 788.8 770.3 773.3 Less: accumulated amortization 216.5 191.6 216.5 177.6 Total intangible assets, net $ 553.8 $ 597.2 $ 553.8 $ 595.7 (1) As of December 31, 2018, we fully amortized and eliminated certain intangibles associated with our trademarks. The following table summarizes total accumulated amortization of our intangible assets at December 31, 2018 and 2017 ( in millions ): CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Customer accounts $ 112.1 $ 89.8 $ 112.1 $ 89.8 Gas gathering, compression and processing contracts 100.8 82.0 100.8 82.0 Trademarks 3.6 19.8 3.6 5.8 Total accumulated amortization $ 216.5 $ 191.6 $ 216.5 $ 177.6
Schedule of Intangible Assets, Future Amortization Expense	Estimated amortization of CEQP’s and CMLP’s intangible assets for the next five years is as follows ( in millions ): Year Ending December 31, 2019 $ 41.7 2020 41.7 2021 41.7 2022 41.7 2023 37.7
Schedule of Accrued Liabilities	Accrued expenses and other liabilities consisted of the following at December 31, 2018 and 2017 ( in millions ): CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Accrued expenses (1) $ 64.8 $ 56.6 $ 63.7 $ 55.5 Accrued property taxes 2.6 4.8 2.6 4.8 Income tax payable 0.3 0.3 0.3 0.3 Interest payable 19.8 20.3 19.8 20.3 Accrued additions to property, plant and equipment 10.5 22.3 10.5 22.2 Capital leases 2.4 1.0 2.4 1.0 Deferred revenue 12.0 0.6 12.0 0.6 Total accrued expenses and other liabilities $ 112.4 $ 105.9 $ 111.3 $ 104.7 (1) Includes $16.2 million of related party accrued expenses at December 31, 2018 related to deposits received from Jackalope, our 50% equity method investment.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Asset Retirement Obligations	The following table presents the changes in the net asset retirement obligations for the years ended December 31, 2018 and 2017 ( in millions ): December 31, 2018 2017 Net asset retirement obligation at January 1 $ 27.5 $ 27.8 Liabilities incurred 0.7 — Liabilities settled (2.2 ) (1.2 ) Accretion expense 1.6 1.4 Change in estimate — (0.5 ) Net asset retirement obligation at December 31 $ 27.6 $ 27.5

Investments in Unconsolidated_2

Investments in Unconsolidated Affiliates (Tables)	12 Months Ended
	Dec. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Distributions and Contributions Distributions Contributions Year Ended December 31, Year Ended December 31, 2018 2017 2016 2018 2017 2016 Stagecoach Gas $ 48.7 $ 47.3 $ 16.0 $ — $ 0.8 $ — Jackalope (1) 32.4 26.3 27.4 49.1 3.5 1.4 Crestwood Permian (2) 14.7 23.4 — 12.6 117.5 — Tres Holdings (3) 5.3 9.0 8.5 2.5 5.6 11.0 PRBIC (1) 1.9 1.6 2.0 0.2 — — Total $ 103.0 $ 107.6 $ 53.9 $ 64.4 $ 127.4 $ 12.4 (1) Jackalope and PRBIC are required to make quarterly distributions of its available cash to its members based on their respective ownership percentage. In February 2019, we received a cash distribution of $11.6 million from Jackalope. (2) On June 21, 2017, we contributed to Crestwood Permian 100% of the equity interest of Crestwood New Mexico at our historical book value of approximately $69.4 million . This contribution was treated as a non-cash transaction between entities under common control. (3) Tres Holdings is required, within 30 days following the end of each quarter, to make quarterly distributions of its available cash (as defined in its limited liability company agreement) to its members based on their respective ownership percentage. Financial Position Data December 31, 2018 2017 Current Assets Non-Current Assets Current Liabilities Non-Current Liabilities Members’ Equity Current Assets Non-Current Assets Current Liabilities Non-Current Liabilities Members’ Equity Stagecoach (1) $ 50.1 $ 1,725.1 $ 4.2 $ 0.9 $ 1,770.1 $ 55.1 $ 1,765.4 $ 7.0 $ 1.4 $ 1,812.1 Crestwood Permian (2) 17.7 372.6 16.8 94.7 278.8 37.6 203.3 33.4 1.8 205.7 Other (3) 59.3 658.0 17.4 129.6 570.3 43.7 597.8 20.0 91.8 529.7 Total $ 127.1 $ 2,755.7 $ 38.4 $ 225.2 $ 2,619.2 $ 136.4 $ 2,566.5 $ 60.4 $ 95.0 $ 2,547.5 (1) As of December 31, 2018 , our equity in the underlying net assets of 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. (2) As of December 31, 2018, the difference of approximately $8.9 million between our equity in Crestwood Permian’s net assets and our investment balance is not subject to amortization. (3) Includes our Jackalope, Tres Holdings and PRBIC equity investments. As of December 31, 2018 , our equity in the underlying net assets of Jackalope, Tres Holdings and PRBIC exceeded our investment balance by approximately $0.4 million , $25.3 million and $5.9 million , respectively. Our net investments in and earnings (loss) from our unconsolidated affiliates are as follows ( in millions, unless otherwise stated): Ownership Percentage Investment Earnings (Loss) from Unconsolidated Affiliates December 31, December 31, Year Ended December 31, 2018 2018 2017 2018 2017 2016 Stagecoach Gas Services LLC 50.00 % $ 830.4 $ 849.8 $ 29.3 $ 25.3 $ 15.9 Jackalope Gas Gathering Services, L.L.C. (1) 50.00 % (1) 210.2 184.9 18.1 10.5 20.8 Crestwood Permian Basin Holdings LLC (2) 50.00 % 104.3 102.0 4.4 8.4 (0.5 ) Tres Palacios Holdings LLC 50.01 % 35.0 37.8 — 2.2 (0.3 ) Powder River Basin Industrial Complex, LLC (3) 50.01 % 8.3 8.5 1.5 1.4 (4.4 ) Total $ 1,188.2 $ 1,183.0 $ 53.3 $ 47.8 $ 31.5 (1) Excludes non-controlling interest related to our investment in Jackalope. See Note 12 for a further discussion of our non-controlling interest related to our investment in Jackalope. (2) Pursuant to the Crestwood Permian limited liability company agreement, we were allocated 100% of Crestwood New Mexico’s earnings through June 30, 2018. Effective July 1, 2018, our equity earnings from Crestwood New Mexico is based on our ownership percentage of Crestwood Permian, which is currently 50% . (3) During the year ended December 31, 2016 , we recorded a reduction of our equity earnings from PRBIC of approximately $5.8 million related to impairments recorded by our equity investee. For a further discussion of these impairments, see Note 2 . Operating Results Data Year Ended December 31, 2018 2017 2016 Operating Revenues Operating Expenses Net Income Operating Revenues Operating Expenses Net Income Operating Revenues Operating Expenses Net Income Stagecoach $ 171.4 $ 79.3 $ 92.1 $ 168.6 $ 77.7 $ 91.1 $ 99.3 $ 44.1 $ 55.3 Crestwood 82.2 81.3 5.7 87.3 74.1 14.1 11.5 10.9 0.6 Other (1) 116.9 81.5 35.6 94.5 69.5 24.8 116.1 103.0 12.9 Total $ 370.5 $ 242.1 $ 133.4 $ 350.4 $ 221.3 $ 130.0 $ 226.9 $ 158.0 $ 68.8 (1) Includes our Jackalope, Tres Holdings and PRBIC equity investments. 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 Jackalope equity investment of less than $0.1 million for each of the years ended December 31, 2018 , 2017 and 2016 , which we amortize over the life of Jackalope’s gathering agreement with Chesapeake Energy Corporation (Chesapeake). We recorded amortization of the excess basis in our Tres Holdings equity investment of approximately $1.3 million for each of the years ended December 31, 2018 , 2017 and 2016 , which we amortize over the life of Tres Palacios’ sublease agreement. We recorded amortization of the excess basis in our PRBIC equity investment of approximately $0.5 million , $0.6 million and $1.6 million for the years ended December 31, 2018 , 2017 and 2016 , which we amortize over the life of PRBIC’s property, plant and equipment.

Risk Management (Tables)

Risk Management (Tables)	12 Months Ended
	Dec. 31, 2018
Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]
Derivatives Not Designated as Hedging Instruments	The following table summarizes the impact to our consolidated statements of operations related to our commodity-based derivatives reflected in costs of products/services sold and operating revenues during the years ended December 31, 2018 , 2017 and 2016 ( in millions ): December 31, 2018 2017 2016 Gain (loss) reflected in costs of product/services sold $ 29.6 $ (31.2 ) $ (7.8 ) Product revenues 343.3 234.1 162.9
Notional Amounts And Terms Of Company's Derivative Financial Instruments	The notional amounts and terms of our derivative financial instruments include the following: December 31, 2018 December 31, 2017 Fixed Price Payor Fixed Price Receiver Fixed Price Payor Fixed Price Receiver Propane, crude and heating oil (MMBbls) 27.8 30.1 15.3 17.5 Natural gas (MMcf) 1,800 1,800 780 660
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table represents the fair value of our commodity derivative instruments with credit-risk-related contingent features and their associated collateral ( in millions ): December 31, 2018 2017 Aggregate fair value of derivative instruments with credit-risk-related contingent features (1) $ 2.2 $ 28.9 NYMEX-related net derivative asset (liability) position (9.4 ) 27.2 NYMEX-related cash collateral posted 21.7 5.6 Cash collateral received 14.2 3.7 (1) At December 31, 2018 and 2017 . we posted less than less than $0.1 million of collateral associated with these derivatives.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2018
Fair Value Disclosures [Abstract]
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	The following table reflects the carrying amount (reduced for deferred financing costs associated with the respective notes) and fair value of our senior notes ( in millions ): December 31, 2018 December 31, 2017 Carrying Amount Fair Value Carrying Amount Fair 2023 Senior Notes $ 693.6 $ 668.1 $ 692.1 $ 728.8 2025 Senior Notes $ 493.4 $ 466.2 $ 492.3 $ 517.9
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 December 31, 2018 and 2017 ( in millions ): December 31, 2018 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 $ 12.4 $ 160.7 $ — $ 173.1 $ (140.3 ) $ 1.9 $ 34.7 Suburban Propane Partners, L.P. units (2) 2.8 — — 2.8 — — 2.8 Total assets at fair value $ 15.2 $ 160.7 $ — $ 175.9 $ (140.3 ) $ 1.9 $ 37.5 Liabilities Liabilities from price risk management $ 7.0 $ 144.7 $ — $ 151.7 $ (140.3 ) $ (5.6 ) $ 5.8 Total liabilities at fair value $ 7.0 $ 144.7 $ — $ 151.7 $ (140.3 ) $ (5.6 ) $ 5.8 December 31, 2017 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 $ 1.1 $ 102.2 $ — $ 103.3 $ (74.6 ) $ (21.5 ) $ 7.2 Suburban Propane Partners, L.P. units (2) 3.5 — — 3.5 — — 3.5 Total assets at fair value $ 4.6 $ 102.2 $ — $ 106.8 $ (74.6 ) $ (21.5 ) $ 10.7 Liabilities Liabilities from price risk management $ 1.4 $ 118.2 $ — $ 119.6 $ (74.6 ) $ 3.9 $ 48.9 Total liabilities at fair value $ 1.4 $ 118.2 $ — $ 119.6 $ (74.6 ) $ 3.9 $ 48.9 (1) Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions as well as cash collateral held or placed with the same counterparties. (2) Amount is reflected in other assets on CEQP’s consolidated balance sheets.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2018
Text Block [Abstract]
Components Of Long-Term Debt	Long-term debt consisted of the following at December 31, 2018 and 2017 , ( in millions ): December 31, 2018 2017 Credit Facility $ 578.2 $ 318.2 2023 Senior Notes 700.0 700.0 2025 Senior Notes 500.0 500.0 Other 1.5 2.4 Less: deferred financing costs, net 26.4 28.4 Total debt 1,753.3 1,492.2 Less: current portion 0.9 0.9 Total long-term debt, less current portion $ 1,752.4 $ 1,491.3
Schedule of Maturities of Long-term Debt	The aggregate maturities of principal amounts on our outstanding long-term debt and other notes payable as of December 31, 2018 for the next five years and in total thereafter are as follows ( in millions ): 2019 $ 0.9 2020 0.2 2021 0.2 2022 0.2 2023 1,278.2 Thereafter 500.0 Total debt $ 1,779.7

Earnings Per Limited Partner _2

Earnings Per Limited Partner Unit (Tables)	12 Months Ended
	Dec. 31, 2018
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 years ended December 31, 2018 , 2017 and 2016 : Year Ended December 31, 2018 2017 2016 Preferred units (1) 7,125,744 7,007,917 6,433,127 Crestwood Niobrara’s preferred units (1) 6,526,495 7,146,663 7,548,624 Subordinated units (2) 438,789 438,789 438,789 Stock-based compensation performance units (2) 365,997 316,980 — (1) See Note 12 for additional information regarding the potential conversion of our preferred units and Crestwood Niobrara’s preferred units to common units. (2) For a description of our subordinated and stock-based compensation performance units, see Note 12 and Note 13 , respectively.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	The (provision) benefit for income taxes for the years ended December 31, 2018 , 2017 , and 2016 consisted of the following (in millions) : CEQP CMLP Year Ended December 31, Year Ended December 31, 2018 2017 2016 2018 2017 (1) 2016 Current: Federal $ (0.5 ) $ (1.1 ) $ (3.2 ) $ 0.1 $ — $ — State (0.3 ) (0.2 ) (0.2 ) (0.2 ) — 0.2 Total current (0.8 ) (1.3 ) (3.4 ) (0.1 ) — 0.2 Deferred: Federal 0.5 2.1 3.0 — — — State 0.2 — 0.1 0.1 — (0.2 ) Total deferred 0.7 2.1 3.1 0.1 — (0.2 ) (Provision) benefit for income taxes $ (0.1 ) $ 0.8 $ (0.3 ) $ — $ — $ — (1) For the year ended December 31, 2017, our benefit for income taxes was not material to CMLP’s consolidated statement of operations.
Schedule of Deferred Tax Assets and Liabilities	Components of our deferred income taxes at December 31, 2018 and 2017 are as follows (in millions). CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Deferred tax asset: Basis difference in stock of company $ 0.2 $ 0.2 $ — $ — Total deferred tax asset 0.2 0.2 — — Deferred tax liability: Basis difference in stock of company (2.8 ) (3.5 ) (0.6 ) (0.7 ) Total deferred tax liability (2.8 ) (3.5 ) (0.6 ) (0.7 ) Net deferred tax liability $ (2.6 ) $ (3.3 ) $ (0.6 ) $ (0.7 )

Partners' Capital (Tables)

Partners' Capital (Tables)	12 Months Ended
	Dec. 31, 2018
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Schedule of Distributions Made to Members or Limited Partners, by Distribution	A summary of CEQP’s limited partner quarterly cash distributions for the years ended December 31, 2018 , 2017 and 2016 is presented below: Record Date Payment Date Per Unit Rate Cash Distributions ( in millions ) 2018 February 7, 2018 February 14, 2018 $ 0.60 $ 42.7 May 8, 2018 May 15, 2018 $ 0.60 42.7 August 7, 2018 August 14, 2018 $ 0.60 42.7 November 7, 2018 November 14, 2018 $ 0.60 42.7 $ 170.8 2017 February 7, 2017 February 14, 2017 $ 0.60 $ 41.8 May 8, 2017 May 15, 2017 $ 0.60 41.8 August 7, 2017 August 14, 2017 $ 0.60 41.8 November 7, 2017 November 14, 2017 $ 0.60 42.2 $ 167.6 2016 February 5, 2016 February 12, 2016 $ 1.375 $ 95.6 May 6, 2016 May 13, 2016 $ 0.60 41.4 August 5, 2016 August 12, 2016 $ 0.60 41.4 November 7, 2016 November 14, 2016 $ 0.60 41.4 $ 219.8

Equity Plans (Tables)

Equity Plans (Tables)	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Disclosure of Share-based Compensation Arrangements by Share-based Payment Award	The following table summarizes information regarding restricted and phantom unit activity during the years ended December 31, 2018 , 2017 and 2016 . Units Weighted-Average Grant Date Fair Value Unvested - January 1, 2016 466,214 $ 69.80 Granted - restricted units 1,067,535 $ 14.58 Granted - phantom units 17,467 $ 15.54 Vested - restricted units (193,295 ) $ 76.82 Forfeited (65,591 ) $ 25.13 Unvested - December 31, 2016 1,292,330 $ 24.67 Granted - restricted units 919,411 $ 25.69 Granted - phantom units 15,849 $ 25.02 Granted - performance units 405,620 $ 30.21 Vested - restricted units (607,115 ) $ 28.00 Vested - performance units (31,106 ) $ 30.27 Forfeited - restricted units (140,137 ) $ 23.73 Forfeited - performance units (24,756 ) $ 30.45 Unvested - December 31, 2017 1,830,096 $ 25.21 Granted - restricted units 1,144,017 $ 25.80 Granted - phantom units 7,750 $ 26.10 Granted - performance units 901 $ 25.60 Vested - restricted units (617,807 ) $ 23.73 Vested - phantom units (105,809 ) $ 49.45 Vested - performance units (11,772 ) $ 28.87 Forfeited - restricted units (53,530 ) $ 23.36 Forfeited - phantom units (6 ) $ 49.45 Forfeited - performance units (5,870 ) $ 30.45 Unvested - December 31, 2018 2,187,970 $ 24.78

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Purchase Commitment, Excluding Long-term Commitment	The following table summarizes CEQP’s and CMLP’s self-insurance reserves at December 31, 2018 and 2017 (in millions) : CEQP CMLP December 31, December 31, 2018 2017 2018 2017 Self-insurance reserves (1) $ 11.3 $ 13.6 $ 9.6 $ 11.6 (1) CEQP and CMLP classified approximately $7.5 million and $6.2 million of their respective balances as other long-term liabilities on their consolidated balance sheets at December 31, 2018 .
Schedule of Future Minimum Rental Payments for Operating Leases	The following table presents the future minimum lease payments under our noncancelable operating leases and the net minimum lease payments under our existing capital leases for the next five years ending December 31 and in total thereafter ( in millions ): Capital Leases Year Ending December 31, Operating Leases Minimum Lease Payments Less Interest Net Present Value Total 2019 $ 22.3 $ 3.0 $ 0.6 $ 2.4 $ 24.7 2020 18.1 3.3 0.4 2.9 21.0 2021 14.4 3.2 0.2 3.0 17.4 2022 9.7 1.9 0.1 1.8 11.5 2023 6.0 — — — 6.0 Thereafter 10.7 — — — 10.7 Total minimum lease payments $ 81.2 $ 11.4 $ 1.3 $ 10.1 $ 91.3

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2018
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	The following table shows revenues, costs of product/services sold, general and administrative expenses and reimbursement of expenses from our affiliates for the years December 31, 2018 , 2017 and 2016 ( in millions ): Year Ended December 31, 2018 2017 2016 Revenues at CEQP and CMLP $ 1.0 $ 1.8 $ 2.6 Costs of product/services sold at CEQP and CMLP (1) $ 134.7 $ 15.3 $ 17.7 Operations and maintenance expenses at CEQP and CMLP (2) $ 28.7 $ 22.3 $ 8.1 General and administrative expenses charged by CEQP to CMLP, net (3) $ 20.7 $ 19.4 $ 13.0 General and administrative expenses at CEQP charged from Crestwood Holdings, net (4) $ (2.7 ) $ (1.7 ) $ (2.2 ) (1) Includes $56.1 million during the year ended December 31, 2018 related to purchases of NGLs from a subsidiary of Crestwood Permian and $78.6 million related to an agency marketing agreement with Ascent Resources - Utica, LLC (Ascent). Amounts presented for the years ended December 31, 2017 and 2016 represent natural gas purchases from Sabine Oil and Gas (Sabine). Ascent and Sabine are affiliates of Crestwood Holdings for the respective periods presented. (2) 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. During the year ended December 31, 2018, we charged $7.9 million to Stagecoach Gas, $3.8 million to Tres Palacios, $15.9 million to Crestwood Permian and $1.1 million to Jackalope. During the year ended December 31, 2017, we charged $8.4 million to Stagecoach Gas, $3.5 million to Tres Palacios, $10.0 million to Crestwood Permian and $0.4 million to Jackalope. During the year ended December 31, 2016, we charged $5.0 million to Stagecoach Gas, $2.7 million to Tres Palacios, and $0.4 million to Jackalope. (3) Includes $24.3 million , $22.4 million and $16.0 million of net unit-based compensation charges allocated from CEQP to CMLP for the years ended December 31, 2018 , 2017 and 2016 . In addition, includes $3.6 million , $3.0 million and $3.0 million of CMLP’s general and administrative costs allocated to CEQP during the years ended December 31, 2018 , 2017 and 2016 . (4) Includes $4.2 million , $3.1 million and $3.2 million of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the years ended December 31, 2018 , 2017 and 2016 .
Schedule of Related Party Receivables and Payables	The following table shows accounts receivable and accounts payable from our affiliates as of December 31, 2018 and 2017 ( in millions ): December 31, 2018 2017 Accounts receivable at CEQP and CMLP $ 4.1 $ 7.1 Accounts payable at CEQP $ 16.1 $ 7.4 Accounts payable at CMLP $ 13.6 $ 5.0

Segments (Tables)

Segments (Tables)	12 Months Ended
	Dec. 31, 2018
Segment Reporting Information [Line Items]
Reportable Segments	Below is a reconciliation of CEQP’s net income (loss) to EBITDA ( in millions ): Year Ended December 31, 2018 2017 2016 Net income (loss) $ 67.0 $ (166.6 ) $ (192.1 ) Add: Interest and debt expense, net 99.2 99.4 125.1 (Gain) loss on modification/extinguishment of debt 0.9 37.7 (10.0 ) Provision (benefit) for income taxes 0.1 (0.8 ) 0.3 Depreciation, amortization and accretion 168.7 191.7 229.6 EBITDA $ 335.9 $ 161.4 $ 152.9 See details in the table below for disaggregation of our revenues (in millions) . Year Ended December 31, 2018 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Intersegment Elimination Total Revenues: Topic 606 revenues Gathering Natural gas $ 134.9 $ — $ — $ — $ 134.9 Crude oil 38.8 — — — 38.8 Water 58.0 — — — 58.0 Processing Natural gas 10.7 — — — 10.7 NGLs — — 6.1 — 6.1 Compression Natural gas 29.1 — — — 29.1 Storage Crude oil 1.8 4.2 — (1.5 ) 4.5 NGLs — — 8.6 — 8.6 Pipeline Crude oil — 7.1 — (2.3 ) 4.8 Transportation Crude oil 2.9 — 5.9 — 8.8 NGLs — — 26.9 — 26.9 Water — — 0.3 — 0.3 Rail Loading Crude oil — 14.3 0.2 (5.2 ) 9.3 NGLs — — 3.1 — 3.1 Product Sales Natural gas 55.8 — 70.9 (16.6 ) 110.1 Crude oil 722.9 — 978.0 (151.3 ) 1,549.6 NGLs 84.2 — 1,247.0 (24.5 ) 1,306.7 Other — 2.0 — (1.5 ) 0.5 Total Topic 606 revenues 1,139.1 27.6 2,347.0 (202.9 ) 3,310.8 Non-Topic 606 revenues (1) — — 343.3 — 343.3 Total revenues $ 1,139.1 $ 27.6 $ 2,690.3 $ (202.9 ) $ 3,654.1 (1) Represents revenues related to our commodity-based derivatives. See Note 7 for additional information related to our price risk management activities. Crestwood Equity Year Ended December 31, 2018 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Corporate Total Revenues $ 946.7 $ 17.1 $ 2,690.3 $ — $ 3,654.1 Intersegment revenues 192.4 10.5 (202.9 ) — — Costs of product/services sold 767.0 0.2 2,362.2 — 3,129.4 Operations and maintenance expense 71.7 3.3 50.8 — 125.8 General and administrative expense — — — 88.1 88.1 Gain (loss) on long-lived assets, net (3.0 ) — (27.3 ) 1.7 (28.6 ) Earnings from unconsolidated affiliates, net 22.5 30.8 — — 53.3 Other income, net — — — 0.4 0.4 EBITDA $ 319.9 $ 54.9 $ 47.1 $ (86.0 ) $ 335.9 Goodwill $ 45.9 $ — $ 92.7 $ — $ 138.6 Total assets $ 2,633.4 $ 1,004.4 $ 612.5 $ 44.2 $ 4,294.5 Purchases of property, plant and equipment $ 294.7 $ 0.6 $ 5.6 $ 4.6 $ 305.5 Year Ended December 31, 2017 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Corporate Total Revenues $ 1,688.2 $ 37.2 $ 2,155.5 $ — $ 3,880.9 Intersegment revenues 134.5 6.7 (141.2 ) — — Costs of product/services sold 1,480.8 0.3 1,893.6 — 3,374.7 Operations and maintenance expense 68.4 4.2 63.4 — 136.0 General and administrative expense — — — 96.5 96.5 Loss on long-lived assets, net (14.4 ) — (48.2 ) (3.0 ) (65.6 ) Goodwill impairment — — (38.8 ) — (38.8 ) Loss on contingent consideration — (57.0 ) — — (57.0 ) Earnings from unconsolidated affiliates, net 18.9 28.9 — — 47.8 Other income, net 0.8 — — 0.5 1.3 EBITDA $ 278.8 $ 11.3 $ (29.7 ) $ (99.0 ) $ 161.4 Goodwill $ 45.9 $ — $ 101.7 $ — $ 147.6 Total assets $ 2,474.1 $ 1,040.6 $ 757.1 $ 13.1 $ 4,284.9 Purchases of property, plant and equipment $ 162.7 $ 1.3 $ 17.7 $ 6.7 $ 188.4 Year Ended December 31, 2016 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Corporate Total Revenues $ 1,118.8 $ 165.3 $ 1,236.4 $ — $ 2,520.5 Intersegment revenues 108.6 4.2 (112.8 ) — — Costs of product/services sold 917.0 5.1 1,003.0 — 1,925.1 Operations and maintenance expense 77.0 21.4 59.7 — 158.1 General and administrative expense — — — 88.2 88.2 Loss on long-lived assets (2.0 ) (32.2 ) (31.4 ) — (65.6 ) Goodwill impairment (8.6 ) (44.9 ) (109.1 ) — (162.6 ) Earnings from unconsolidated affiliates, net 20.3 11.2 — — 31.5 Other income, net — — — 0.5 0.5 EBITDA $ 243.1 $ 77.1 $ (79.6 ) $ (87.7 ) $ 152.9 Purchases of property, plant and equipment $ 76.6 $ 3.3 $ 19.1 $ 1.7 $ 100.7
CMLP
Segment Reporting Information [Line Items]
Reportable Segments	Below is a reconciliation of CMLP’s net income (loss) to EBITDA ( in millions ): Year Ended December 31, 2018 2017 2016 Net income (loss) $ 58.6 $ (175.5 ) $ (197.5 ) Add: Interest and debt expense, net 99.2 99.4 125.1 (Gain) loss on modification/extinguishment of debt 0.9 37.7 (10.0 ) Depreciation, amortization and accretion 181.4 202.7 240.5 EBITDA $ 340.1 $ 164.3 $ 158.1 Crestwood Midstream Year Ended December 31, 2018 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Corporate Total Revenues $ 946.7 $ 17.1 $ 2,690.3 $ — $ 3,654.1 Intersegment revenues 192.4 10.5 (202.9 ) — — Costs of product/services sold 767.0 0.2 2,362.2 — 3,129.4 Operations and maintenance expense 71.7 3.3 50.8 — 125.8 General and administrative expense — — — 83.5 83.5 Gain (loss) on long-lived assets, net (3.0 ) — (27.3 ) 1.7 (28.6 ) Earnings from unconsolidated affiliates, net 22.5 30.8 — — 53.3 EBITDA $ 319.9 $ 54.9 $ 47.1 $ (81.8 ) $ 340.1 Goodwill $ 45.9 $ — $ 92.7 $ — $ 138.6 Total assets $ 2,807.1 $ 1,004.4 $ 612.5 $ 38.0 $ 4,462.0 Purchases of property, plant and equipment $ 294.7 $ 0.6 $ 5.6 $ 4.6 $ 305.5 Year Ended December 31, 2017 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Corporate Total Revenues $ 1,688.2 $ 37.2 $ 2,155.5 $ — $ 3,880.9 Intersegment revenues 134.5 6.7 (141.2 ) — — Costs of product/services sold 1,480.8 0.3 1,893.6 — 3,374.7 Operations and maintenance expense 68.4 4.2 63.4 — 136.0 General and administrative expense — — — 93.1 93.1 Loss on long-lived assets, net (14.4 ) — (48.2 ) (3.0 ) (65.6 ) Goodwill impairment — — (38.8 ) — (38.8 ) Loss on contingent consideration — (57.0 ) — — (57.0 ) Earnings from unconsolidated affiliates, net 18.9 28.9 — — 47.8 Other income, net 0.8 — — — 0.8 EBITDA $ 278.8 $ 11.3 $ (29.7 ) $ (96.1 ) $ 164.3 Goodwill $ 45.9 $ — $ 101.7 $ — $ 147.6 Total assets $ 2,662.0 $ 1,040.6 $ 757.1 $ 6.6 $ 4,466.3 Purchases of property, plant and equipment $ 162.7 $ 1.3 $ 17.7 $ 6.7 $ 188.4 Year Ended December 31, 2016 Gathering and Processing Storage and Transportation Marketing, Supply and Logistics Corporate Total Revenues $ 1,118.8 $ 165.3 $ 1,236.4 $ — $ 2,520.5 Intersegment revenues 108.6 4.2 (112.8 ) — — Costs of product/services sold 917.0 5.1 1,003.0 — 1,925.1 Operations and maintenance expense 77.0 18.3 59.7 — 155.0 General and administrative expense — — — 85.6 85.6 Loss on long-lived assets, net (2.0 ) (32.2 ) (31.4 ) — (65.6 ) Goodwill impairment (8.6 ) (44.9 ) (109.1 ) — (162.6 ) Earnings from unconsolidated affiliates, net 20.3 11.2 — — 31.5 EBITDA $ 243.1 $ 80.2 $ (79.6 ) $ (85.6 ) $ 158.1 Purchases of property, plant and equipment $ 76.6 $ 3.3 $ 19.1 $ 1.7 $ 100.7

Condensed Consolidating Finan_2

Condensed Consolidating Financial Information (Tables)	12 Months Ended
	Dec. 31, 2018
Condensed Financial Information Disclosure [Abstract]
Condensed Consolidating Balance Sheet	Crestwood Midstream Partners LP Condensed Consolidating Balance Sheet December 31, 2018 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Assets Current assets: Cash $ 0.2 $ — $ — $ — $ 0.2 Restricted cash 16.3 — — — 16.3 Accounts receivable — 246.3 19.9 (16.3 ) 249.9 Inventory — 64.6 — — 64.6 Other current assets — 46.0 — — 46.0 Total current assets 16.5 356.9 19.9 (16.3 ) 377.0 Property, plant and equipment, net — 2,202.3 — — 2,202.3 Goodwill and intangible assets, net — 692.4 — — 692.4 Investments in consolidated affiliates 3,800.4 — — (3,800.4 ) — Investments in unconsolidated affiliates — — 1,188.2 — 1,188.2 Other non-current assets — 2.1 — — 2.1 Total assets $ 3,816.9 $ 3,253.7 $ 1,208.1 $ (3,816.7 ) $ 4,462.0 Liabilities and partners’ capital Current liabilities: Accounts payable $ 16.3 $ 210.5 $ — $ (16.3 ) $ 210.5 Other current liabilities 20.0 81.8 16.2 — 118.0 Total current liabilities 36.3 292.3 16.2 (16.3 ) 328.5 Long-term liabilities: Long-term debt, less current portion 1,752.4 — — — 1,752.4 Other long-term liabilities — 114.0 57.0 — 171.0 Deferred income taxes — 0.6 — — 0.6 Partners’ capital 2,028.2 2,846.8 953.6 (3,800.4 ) 2,028.2 Interest of non-controlling partner in subsidiary — — 181.3 — 181.3 Total partners’ capital 2,028.2 2,846.8 1,134.9 (3,800.4 ) 2,209.5 Total liabilities and partners’ capital $ 3,816.9 $ 3,253.7 $ 1,208.1 $ (3,816.7 ) $ 4,462.0 Crestwood Midstream Partners LP Condensed Consolidating Balance Sheet December 31, 2017 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Assets Current assets: Cash $ 1.0 $ — $ — $ — $ 1.0 Accounts receivable — 439.7 2.9 — 442.6 Inventory — 68.4 — — 68.4 Other current assets — 18.1 — — 18.1 Total current assets 1.0 526.2 2.9 — 530.1 Property, plant and equipment, net — 2,007.5 — — 2,007.5 Goodwill and intangible assets, net — 743.3 — — 743.3 Investments in consolidated affiliates 3,705.4 — — (3,705.4 ) — Investments in unconsolidated affiliates — — 1,183.0 — 1,183.0 Other non-current assets — 2.4 — — 2.4 Total assets $ 3,706.4 $ 3,279.4 $ 1,185.9 $ (3,705.4 ) $ 4,466.3 Liabilities and partners’ capital Current liabilities: Accounts payable $ — $ 346.8 $ — $ — $ 346.8 Other current liabilities 20.5 134.0 — — 154.5 Total current liabilities 20.5 480.8 — — 501.3 Long-term liabilities: Long-term debt, less current portion 1,490.5 0.8 — — 1,491.3 Other long-term liabilities — 45.6 57.0 — 102.6 Deferred income taxes — 0.7 — — 0.7 Partners’ capital 2,195.4 2,751.5 953.9 (3,705.4 ) 2,195.4 Interest of non-controlling partner in subsidiary — — 175.0 — 175.0 Total partners’ capital 2,195.4 2,751.5 1,128.9 (3,705.4 ) 2,370.4 Total liabilities and partners’ capital $ 3,706.4 $ 3,279.4 $ 1,185.9 $ (3,705.4 ) $ 4,466.3
Condensed Consolidating Statements of Operations	Crestwood Midstream Partners LP Condensed Consolidating Statements of Operations Year Ended December 31, 2018 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Revenues $ — $ 3,654.1 $ — $ — $ 3,654.1 Costs of product/services sold — 3,129.4 — — 3,129.4 Operating expenses and other: Operations and maintenance — 125.8 — — 125.8 General and administrative 55.1 28.4 — — 83.5 Depreciation, amortization and accretion — 181.4 — — 181.4 Loss on long-lived assets, net — 28.6 — — 28.6 55.1 364.2 — — 419.3 Operating income (loss) (55.1 ) 160.5 — — 105.4 Earnings from unconsolidated affiliates, net — — 53.3 — 53.3 Interest and debt expense, net (99.2 ) — — — (99.2 ) Loss on modification/extinguishment of debt (0.9 ) — — — (0.9 ) Equity in net income (loss) of subsidiaries 197.6 — — (197.6 ) — Net income (loss) 42.4 160.5 53.3 (197.6 ) 58.6 Net income attributable to non-controlling partner — — 16.2 — 16.2 Net income (loss) attributable to Crestwood Midstream Partners LP $ 42.4 $ 160.5 $ 37.1 $ (197.6 ) $ 42.4 Crestwood Midstream Partners LP Condensed Consolidating Statements of Operations Year Ended December 31, 2017 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Revenues $ — $ 3,880.9 $ — $ — $ 3,880.9 Costs of product/services sold — 3,374.7 — — 3,374.7 Operating expenses and other: Operations and maintenance — 136.0 — — 136.0 General and administrative 67.6 25.5 — — 93.1 Depreciation, amortization and accretion — 202.7 — — 202.7 Loss on long-lived assets, net — 65.6 — — 65.6 Goodwill impairment — 38.8 — — 38.8 Loss on contingent consideration — — 57.0 — 57.0 67.6 468.6 57.0 — 593.2 Operating income (loss) (67.6 ) 37.6 (57.0 ) — (87.0 ) Earnings from unconsolidated affiliates, net — — 47.8 — 47.8 Interest and debt expense, net (99.4 ) — — — (99.4 ) Loss on modification/extinguishment of debt (37.7 ) — — — (37.7 ) Other income, net — 0.8 — — 0.8 Equity in net income (loss) of subsidiaries 3.9 — — (3.9 ) — Net income (loss) (200.8 ) 38.4 (9.2 ) (3.9 ) (175.5 ) Net income attributable to non-controlling partner — — 25.3 — 25.3 Net income (loss) attributable to Crestwood Midstream Partners LP $ (200.8 ) $ 38.4 $ (34.5 ) $ (3.9 ) $ (200.8 ) Crestwood Midstream Partners Condensed Consolidating Statements of Operations Year Ended December 31, 2016 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Revenues $ — $ 2,520.5 $ — $ — $ 2,520.5 Costs of product/services sold — 1,925.1 — — 1,925.1 Operating expenses and other: Operations and maintenance — 155.0 — — 155.0 General and administrative 66.4 19.2 — — 85.6 Depreciation, amortization and accretion — 240.5 — — 240.5 Loss on long-lived assets, net — 65.6 — — 65.6 Goodwill impairment — 162.6 — — 162.6 66.4 642.9 — — 709.3 Operating loss (66.4 ) (47.5 ) — — (113.9 ) Earnings from unconsolidated affiliates, net — — 31.5 — 31.5 Interest and debt expense, net (125.1 ) — — — (125.1 ) Gain on modification/extinguishment of debt 10.0 — — — 10.0 Equity in net income (loss) of subsidiaries (40.2 ) — — 40.2 — Net income (loss) (221.7 ) (47.5 ) 31.5 40.2 (197.5 ) Net income attributable to non-controlling partner — — 24.2 — 24.2 Net income (loss) attributable to Crestwood Midstream Partners LP $ (221.7 ) $ (47.5 ) $ 7.3 $ 40.2 $ (221.7 )
Condensed Consolidating Statements of Cash Flows	Crestwood Midstream Partners LP Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2018 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Cash flows from operating activities: $ (131.7 ) $ 339.2 $ 53.0 $ — $ 260.5 Cash flows from investing activities: Purchases of property, plant and equipment — (305.5 ) — — (305.5 ) Investment in unconsolidated affiliates — — (64.4 ) — (64.4 ) Capital distributions from unconsolidated affiliates — — 49.2 — 49.2 Net proceeds from sale of assets — 79.5 — — 79.5 Capital distributions from consolidated affiliates 27.9 — — (27.9 ) — Net cash provided by (used in) investing activities 27.9 (226.0 ) (15.2 ) (27.9 ) (241.2 ) Cash flows from financing activities: Proceeds from the issuance of long-term debt 2,274.8 — — — 2,274.8 Payments on long-term debt (2,014.8 ) (0.9 ) — — (2,015.7 ) Payments on capital leases — (1.6 ) — — (1.6 ) Payments for debt-related deferred costs (5.7 ) — — — (5.7 ) Distributions to partners (238.4 ) — (9.9 ) — (248.3 ) Distributions to parent — — (27.9 ) 27.9 — Taxes paid for unit-based compensation vesting — (7.4 ) — — (7.4 ) Change in intercompany balances 103.4 (103.4 ) — — — Other — 0.1 — — 0.1 Net cash provided by (used in) financing activities 119.3 (113.2 ) (37.8 ) 27.9 (3.8 ) Net change in cash and restricted cash 15.5 — — — 15.5 Cash and restricted cash at beginning of period 1.0 — — — 1.0 Cash and restricted cash at end of period $ 16.5 $ — $ — $ — $ 16.5 Crestwood Midstream Partners LP Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2017 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Cash flows from operating activities: $ (162.3 ) $ 379.2 $ 45.3 $ — $ 262.2 Cash flows from investing activities: Purchases of property, plant and equipment — (188.4 ) — — (188.4 ) Investment in unconsolidated affiliates — — (58.0 ) — (58.0 ) Capital distributions from unconsolidated affiliates — — 59.9 — 59.9 Net proceeds from sale of assets — 225.2 — — 225.2 Capital distributions from consolidated affiliates 4.3 — — (4.3 ) — Net cash provided by (used in) investing activities 4.3 36.8 1.9 (4.3 ) 38.7 Cash flows from financing activities: Proceeds from the issuance of long-term debt 2,838.6 — — — 2,838.6 Payments on long-term debt (2,912.6 ) (1.3 ) — — (2,913.9 ) Payments on capital leases — (2.7 ) — — (2.7 ) Payments for deferred financing costs (1.0 ) — — — (1.0 ) Redemption of non-controlling interest — — (202.7 ) — (202.7 ) Net proceeds from issuance of non-controlling interest — — 175.0 — 175.0 Distributions to partners (174.0 ) — (15.2 ) — (189.2 ) Distributions to parent — — (4.3 ) 4.3 — Taxes paid for unit-based compensation vesting — (5.5 ) — — (5.5 ) Change in intercompany balances 406.7 (406.7 ) — — — Other — 0.2 — — 0.2 Net cash provided by (used in) financing activities 157.7 (416.0 ) (47.2 ) 4.3 (301.2 ) Net change in cash and restricted cash (0.3 ) — — — (0.3 ) Cash and restricted cash at beginning of period 1.3 — — — 1.3 Cash and restricted cash at end of period $ 1.0 $ — $ — $ — $ 1.0 Crestwood Midstream Partners LP Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2016 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Cash flows from operating activities: $ (188.0 ) $ 502.8 $ 39.0 $ — $ 353.8 Cash flows from investing activities: Acquisitions, net of cash acquired — (7.2 ) — — (7.2 ) Purchases of property, plant and equipment — (100.7 ) — — (100.7 ) Investment in unconsolidated affiliates — — (12.4 ) — (12.4 ) Capital distributions from unconsolidated affiliates — — 14.8 — 14.8 Net proceeds from sale of assets — 972.7 — — 972.7 Capital contributions to consolidated affiliates 26.2 — — (26.2 ) — Net cash provided by (used in) investing activities 26.2 864.8 2.4 (26.2 ) 867.2 Cash flows from financing activities: Proceeds from the issuance of long-term debt 1,565.3 — — — 1,565.3 Payments on long-term debt (2,535.3 ) (0.8 ) — — (2,536.1 ) Payments on capital leases — (1.9 ) — — (1.9 ) Payments for deferred financing costs (3.5 ) — — — (3.5 ) Distributions to partners (227.6 ) — (15.2 ) — (242.8 ) Distributions to parent — — (26.2 ) 26.2 — Taxes paid for unit-based compensation vesting — (0.8 ) — — (0.8 ) Change in intercompany balances 1,364.1 (1,364.1 ) — — — Net cash provided by (used in) financing activities 163.0 (1,367.6 ) (41.4 ) 26.2 (1,219.8 ) Net change in cash and restricted cash 1.2 — — — 1.2 Cash and restricted cash at beginning of period 0.1 — — — 0.1 Cash and restricted cash at end of period $ 1.3 $ — $ — $ — $ 1.3

Organization and Description _2

Organization and Description of Business (Narrative) (Detail) - 12 months ended Dec. 31, 2018	Total	segment	reporting_units
Partnership Organization And Basis Of Presentation [Line Items]
Number of operating segments		3	3
Crestwood Equity Partners LP
Partnership Organization And Basis Of Presentation [Line Items]
Limited partnership interest	99.90%
Crestwood Gas Services GP, LLC
Partnership Organization And Basis Of Presentation [Line Items]
Limited partnership interest	0.10%
Common Unit Capital | Crestwood Holdings
Partnership Organization And Basis Of Presentation [Line Items]
General partner ownership percentage	25.00%

Basis of Presentation and Sum_4

Basis of Presentation and Summary of Significant Accounting Policies (Narrative) (Details) - USD ($) $ in Millions	Jun. 21, 2017	Oct. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 01, 2019	Jan. 01, 2018
Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment, net			$ 2,029.7	$ 1,820.8
Deferred Revenue				0.6
Increase (Decrease) in Restricted Cash			16.3
Inventory			64.6	68.4
Contribution of Property	$ 69
Net proceeds from sale of assets			79.5	225.2	$ 972.7
Debt Issuance Costs, Net			26.4	28.4
Property, plant and equipment			$ 2,598.1	2,285.2
Percentage of gross income from qualifying sources required to be subject to federal income tax, minimum			90.00%
Goodwill impairment			$ 0	38.8	162.6
Goodwill, Written off Related to Sale of Business Unit			9
Liabilities, Current			332.1	505.1
West Coast
Summary Of Significant Accounting Policies [Line Items]
Impairment of intangible assets				0.8
Goodwill impairment				2.4	0
Marcellus
Summary Of Significant Accounting Policies [Line Items]
Goodwill impairment				0	8.6
Trucking
Summary Of Significant Accounting Policies [Line Items]
Impairment of intangible assets					31.4
Goodwill impairment				0	29.5
Natural Gas Liquids
Summary Of Significant Accounting Policies [Line Items]
Inventory			64.2	67.9
CMLP
Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment, net			2,202.3	2,007.5
Inventory			64.6	68.4
Net proceeds from sale of assets			79.5	225.2	972.7
Property, plant and equipment			2,928.2	2,615.3
Deferred revenue			12	0.6
Goodwill impairment			0	38.8	162.6
Goodwill, Impaired, Accumulated Impairment Loss			1,399.3
Liabilities, Current			328.5	501.3
Crestwood Equity Partners LP
Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment, net			2,029.7	1,820.8
Property, plant and equipment			2,598.1	2,285.2
Deferred revenue			12	0.6
Goodwill impairment				$ 38.8	162.6
Goodwill, Impaired, Accumulated Impairment Loss			$ 1,656.5
Stagecoach Gas Services LLC
Summary Of Significant Accounting Policies [Line Items]
Net proceeds from sale of assets					3
Equity method ownership percentage			50.00%
Stagecoach Gas Services LLC | CEGP
Summary Of Significant Accounting Policies [Line Items]
Net proceeds from sale of assets					$ 975
Stagecoach Gas Services LLC | CMLP
Summary Of Significant Accounting Policies [Line Items]
Equity method ownership percentage					50.00%
Measurement Input, Discount Rate
Summary Of Significant Accounting Policies [Line Items]
Fair Value Inputs				12.00%	10.00%
Measurement Input, Discount Rate | Minimum
Summary Of Significant Accounting Policies [Line Items]
Fair Value Inputs				10.00%
Measurement Input, Discount Rate | Maximum
Summary Of Significant Accounting Policies [Line Items]
Fair Value Inputs				12.00%	19.00%
Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment, net							$ 87.6
Deferred Revenue							$ 69.1
Accounting Standards Update 2016-02
Summary Of Significant Accounting Policies [Line Items]
Assets, Noncurrent						$ 69
Liabilities, Current						19
Liabilities, Noncurrent						$ 50
Marketing Supply and Logistics
Summary Of Significant Accounting Policies [Line Items]
Goodwill impairment				$ 38.8	$ 109.1
Marketing Supply and Logistics | CMLP
Summary Of Significant Accounting Policies [Line Items]
Goodwill impairment				38.8	$ 109.1
West Coast | Marketing Supply and Logistics
Summary Of Significant Accounting Policies [Line Items]
Property, Plant and Equipment, Gross, Period Increase (Decrease)		$ (61.8)
Disposal Group, Including Discontinued Operation, Consideration		$ 70.5
Gain (Loss) on Sale of Assets and Asset Impairment Charges			$ 26.9	$ 81.4

Basis of Presentation and Sum_5

Basis of Presentation and Summary of Significant Accounting Policies (Estimated Useful Lives Of Property, Plant And Equipment) (Detail)	12 Months Ended
	Dec. 31, 2018
Gathering systems and pipelines and related assets | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	15 years
Gathering systems and pipelines and related assets | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	20 years
Facilities and equipment | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	3 years
Facilities and equipment | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	25 years
Buildings, land, rights-of-way, storage rights and easements | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	1 year
Buildings, land, rights-of-way, storage rights and easements | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	40 years
Office furniture and fixtures | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	5 years
Office furniture and fixtures | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	10 years
Vehicles | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	5 years
Vehicles | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	5 years

Basis of Presentation and Sum_6

Basis of Presentation and Summary of Significant Accounting Policies (Estimated Economic Lives Of Intangible Assets) (Detail)	12 Months Ended
	Dec. 31, 2018
Customer Relationships
Finite-Lived Intangible Assets [Line Items]
Weighted-Average Life (years)	20 years
Maximum | Trademarks
Finite-Lived Intangible Assets [Line Items]
Weighted-Average Life (years)	10 years

Basis of Presentation and Sum_7

Basis of Presentation and Summary of Significant Accounting Policies (Goodwill, by Reporting Unit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Goodwill [Roll Forward]
Beginning Balance	$ 147.6
Goodwill Impairments during the Period	0	$ 38.8	$ 162.6
Goodwill, Transfers	0
Goodwill, Written off Related to Sale of Business Unit	(9)
Ending Balance	138.6	147.6
Goodwill, Other Increase (Decrease)	(9)	(12.6)
Marcellus
Goodwill [Roll Forward]
Beginning Balance	0	0
Goodwill Impairments during the Period		0	8.6
Ending Balance	0	0	0
Arrow
Goodwill [Roll Forward]
Beginning Balance	45.9	45.9
Goodwill Impairments during the Period		0	0
Ending Balance	45.9	45.9	45.9
COLT
Goodwill [Roll Forward]
Beginning Balance	0	0
Goodwill Impairments during the Period		0	44.9
Ending Balance		0	0
West Coast
Goodwill [Line Items]
Impairment of intangible assets		0.8
Goodwill [Roll Forward]
Beginning Balance	0	2.4
Goodwill Impairments during the Period		2.4	0
Ending Balance	0	0	2.4
NGL Marketing and Logistics
Goodwill [Roll Forward]
Goodwill, Transfers	101.7
Goodwill, Written off Related to Sale of Business Unit	(9)
Ending Balance	92.7
Supply and Logistics
Goodwill [Roll Forward]
Beginning Balance	101.7	101.7
Goodwill Impairments during the Period		0	65.5
Goodwill, Transfers	(101.7)
Ending Balance	0	101.7	101.7
Storage and Terminals
Goodwill [Roll Forward]
Beginning Balance	0	36.4
Goodwill Impairments during the Period		36.4	14.1
Ending Balance	0	0	36.4
US Salt
Goodwill [Roll Forward]
Beginning Balance	0	12.6
Goodwill Impairments during the Period		0	0
Goodwill, Written off Related to Sale of Business Unit		(12.6)
Ending Balance	0	0	12.6
Trucking
Goodwill [Line Items]
Impairment of intangible assets			31.4
Goodwill [Roll Forward]
Beginning Balance	0	0
Goodwill Impairments during the Period		0	29.5
Ending Balance	0	0	0
CMLP
Goodwill [Roll Forward]
Beginning Balance	147.6
Goodwill Impairments during the Period	0	38.8	162.6
Ending Balance	138.6	147.6
Crestwood Equity Partners LP
Goodwill [Roll Forward]
Beginning Balance	147.6	199
Goodwill Impairments during the Period		38.8	162.6
Ending Balance	138.6	147.6	199
Marketing Supply and Logistics
Goodwill [Roll Forward]
Beginning Balance	101.7
Goodwill Impairments during the Period		38.8	109.1
Ending Balance	92.7	101.7
Marketing Supply and Logistics | CMLP
Goodwill [Roll Forward]
Beginning Balance	101.7
Goodwill Impairments during the Period		38.8	$ 109.1
Ending Balance	$ 92.7	$ 101.7

Basis of Presentation and Sum_8

Basis of Presentation and Summary of Significant Accounting Policies (Revenue Recognition) (Details) - USD ($) $ in Millions	Jan. 01, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment		$ 2,598.1	$ 2,285.2
Revenues		3,654.1	3,880.9	$ 2,520.5
ASC 606 Accounts Receivable		$ 209.7
Revenue, remaining performance obligations, expected timing of satisfaction, period		13 years
Contract with Customer, Asset, Gross, Noncurrent	$ 1.1	$ 1
Contract with Customer, Liability, Current	12.2	12
Contract with Customer, Liability, Noncurrent	60.6	65.4
Contract with Customer, Liability, Revenue Recognized		12.2
Depreciation, amortization and accretion		168.7	191.7	229.6
Earnings from unconsolidated affiliates, net		53.3	47.8	31.5
Net income (loss)		67	(166.6)	(192.1)
Less: accumulated depreciation and depletion		568.4	464.4
Investments in unconsolidated affiliates		1,188.2	1,183
Accrued expenses and other liabilities		112.4	105.9
Other long-term liabilities		173.6	104.7
Partners' capital		1,240.5	1,393.5
Total CEQP/CMLP partners’ capital		1,852.5	2,005.5
Deferred Revenue			0.6
Property, plant and equipment, net		2,029.7	1,820.8
Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Deferred Revenue	69.1
Property, plant and equipment, net	87.6
Capital Reimbursements | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Adoption, Quantification	18.5
Contracts with Increasing (Decreasing) Rates per Unit | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Adoption, Quantification	1.5
Product
Summary Of Significant Accounting Policies [Line Items]
Revenues		3,309.7	3,462.2	1,969.8
Cost of Goods and Services Sold		2,950.5	3,309.5	1,851.9
Service
Summary Of Significant Accounting Policies [Line Items]
Revenues		344.4	418.7	550.7
Cost of Goods and Services Sold		44.2	49.9	55.5
Gathering and Processing Segment | Product
Summary Of Significant Accounting Policies [Line Items]
Revenues		670.5	1,369.1	825.5
Gathering and Processing Segment | Service
Summary Of Significant Accounting Policies [Line Items]
Revenues		276.1	317.3	290.7
Marketing Supply and Logistics
Summary Of Significant Accounting Policies [Line Items]
Revenues		2,690.3	2,155.5	1,236.4
Earnings from unconsolidated affiliates, net		0	0	0
Marketing Supply and Logistics | Product
Summary Of Significant Accounting Policies [Line Items]
Revenues		2,639.2	2,093.1	1,144.3
Marketing Supply and Logistics | Service
Summary Of Significant Accounting Policies [Line Items]
Revenues		50.2	62.4	92.1
Calculated under Revenue Guidance in Effect before Topic 606 | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment		2,480.1
Depreciation, amortization and accretion		163.7
Earnings from unconsolidated affiliates, net		63
Net income (loss)		69.5
Less: accumulated depreciation and depletion		551.2
Investments in unconsolidated affiliates		1,207.4
Accrued expenses and other liabilities		101.2
Other long-term liabilities		108.2
Partners' capital		1,235.5
Calculated under Revenue Guidance in Effect before Topic 606 | Product | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Cost of Goods and Services Sold		3,977.3
Calculated under Revenue Guidance in Effect before Topic 606 | Gathering and Processing Segment | Product | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Revenues		1,643.1
Calculated under Revenue Guidance in Effect before Topic 606 | Gathering and Processing Segment | Service | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Revenues		318.9
Calculated under Revenue Guidance in Effect before Topic 606 | Marketing Supply and Logistics | Service | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Revenues		49.4
Difference between Revenue Guidance in Effect before and after Topic 606 | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment		118
Depreciation, amortization and accretion		5
Earnings from unconsolidated affiliates, net		(9.7)
Net income (loss)		(2.5)
Less: accumulated depreciation and depletion		17.2
Investments in unconsolidated affiliates		(19.2)
Accrued expenses and other liabilities		11.2
Other long-term liabilities		65.4
Partners' capital		5
Difference between Revenue Guidance in Effect before and after Topic 606 | Product | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Cost of Goods and Services Sold		(1,026.8)
Difference between Revenue Guidance in Effect before and after Topic 606 | Gathering and Processing Segment | Product | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Revenues		(972.6)
Difference between Revenue Guidance in Effect before and after Topic 606 | Gathering and Processing Segment | Service | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Revenues		(42.8)
Difference between Revenue Guidance in Effect before and after Topic 606 | Marketing Supply and Logistics | Service | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Revenues		0.8
CMLP
Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment		2,928.2	2,615.3
Revenues		3,654.1	3,880.9	2,520.5
Depreciation, amortization and accretion		181.4	202.7	240.5
Earnings from unconsolidated affiliates, net		53.3	47.8	31.5
Net income (loss)		58.6	(175.5)	(197.5)
Less: accumulated depreciation and depletion		725.9	607.8
Investments in unconsolidated affiliates		1,188.2	1,183
Accrued expenses and other liabilities		111.3	104.7
Other long-term liabilities		171	102.6
Total CEQP/CMLP partners’ capital		2,028.2	2,195.4
Property, plant and equipment, net		2,202.3	2,007.5
CMLP | Product
Summary Of Significant Accounting Policies [Line Items]
Revenues		3,309.7	3,462.2	1,969.8
Cost of Goods and Services Sold		2,950.5	3,309.5	1,851.9
CMLP | Service
Summary Of Significant Accounting Policies [Line Items]
Revenues		344.4	418.7	550.7
Cost of Goods and Services Sold		44.2	49.9	55.5
CMLP | Gathering and Processing Segment | Product
Summary Of Significant Accounting Policies [Line Items]
Revenues		670.5	1,369.1	825.5
CMLP | Gathering and Processing Segment | Service
Summary Of Significant Accounting Policies [Line Items]
Revenues		276.1	317.3	290.7
CMLP | Marketing Supply and Logistics
Summary Of Significant Accounting Policies [Line Items]
Revenues		2,690.3	2,155.5	1,236.4
Earnings from unconsolidated affiliates, net		0	0	0
CMLP | Marketing Supply and Logistics | Product
Summary Of Significant Accounting Policies [Line Items]
Revenues		2,639.2	2,093.1	1,144.3
CMLP | Marketing Supply and Logistics | Service
Summary Of Significant Accounting Policies [Line Items]
Revenues		50.2	62.4	92.1
CMLP | Calculated under Revenue Guidance in Effect before Topic 606 | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment		2,810.2
Depreciation, amortization and accretion		176.4
Earnings from unconsolidated affiliates, net		63
Net income (loss)		61.1
Less: accumulated depreciation and depletion		708.7
Investments in unconsolidated affiliates		1,207.4
Accrued expenses and other liabilities		100.1
Other long-term liabilities		105.6
Total CEQP/CMLP partners’ capital		2,023.2
CMLP | Calculated under Revenue Guidance in Effect before Topic 606 | Product | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Cost of Goods and Services Sold		3,977.3
CMLP | Calculated under Revenue Guidance in Effect before Topic 606 | Gathering and Processing Segment | Product | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Revenues		1,643.1
CMLP | Calculated under Revenue Guidance in Effect before Topic 606 | Gathering and Processing Segment | Service | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Revenues		318.9
CMLP | Calculated under Revenue Guidance in Effect before Topic 606 | Marketing Supply and Logistics | Service | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Revenues		49.4
CMLP | Difference between Revenue Guidance in Effect before and after Topic 606 | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment		118
Depreciation, amortization and accretion		5
Earnings from unconsolidated affiliates, net		(9.7)
Net income (loss)		(2.5)
Less: accumulated depreciation and depletion		17.2
Investments in unconsolidated affiliates		(19.2)
Accrued expenses and other liabilities		11.2
Other long-term liabilities		65.4
Total CEQP/CMLP partners’ capital		5
CMLP | Difference between Revenue Guidance in Effect before and after Topic 606 | Product | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Cost of Goods and Services Sold		(1,026.8)
CMLP | Difference between Revenue Guidance in Effect before and after Topic 606 | Gathering and Processing Segment | Product | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Revenues		(972.6)
CMLP | Difference between Revenue Guidance in Effect before and after Topic 606 | Gathering and Processing Segment | Service | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Revenues		(42.8)
CMLP | Difference between Revenue Guidance in Effect before and after Topic 606 | Marketing Supply and Logistics | Service | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
Revenues		0.8
Jackalope Gas Gathering Services, LLC
Summary Of Significant Accounting Policies [Line Items]
Earnings from unconsolidated affiliates, net		18.1	10.5	$ 20.8
Investments in unconsolidated affiliates		210.2	$ 184.9
Jackalope Gas Gathering Services, LLC | Accounting Standards Update 2014-09
Summary Of Significant Accounting Policies [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Adoption, Quantification	$ 9.5
New Accounting Pronouncement, Equity Earnings Decrease		$ 9.7

Basis of Presentation and Sum_9

Basis of Presentation and Summary of Significant Accounting Policies (Remaining Performance Obligations) (Details) $ in Millions	Dec. 31, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligations, expected timing of satisfaction, period	13 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligations, amount	$ 32.5
Revenue, remaining performance obligations, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligations, amount	$ 23.5
Revenue, remaining performance obligations, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligations, amount	$ 9.4
Revenue, remaining performance obligations, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligations, amount	$ 7.3
Revenue, remaining performance obligations, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligations, amount	$ 7.3
Revenue, remaining performance obligations, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligations, amount	$ 83.3
Revenue, remaining performance obligations, expected timing of satisfaction, period

Divestitures (Narrative) (Detai

Divestitures (Narrative) (Details) - Marketing Supply and Logistics - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Oct. 31, 2018	Dec. 31, 2018	Dec. 31, 2017
West Coast
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal Group, Including Discontinued Operation, Consideration	$ 70.5
Property, Plant and Equipment, Gross, Period Decrease	61.8
Goodwill, Period Decrease	9
Decrease in Other Operating Assets	$ 26.6
Gain (Loss) on Sale of Assets and Asset Impairment Charges		$ 26.9	$ 81.4
US Salt, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal Group, Including Discontinued Operation, Consideration			223.6
Property, Plant and Equipment, Gross, Period Decrease			157.4
Goodwill, Period Decrease			12.6
Decrease in Intangible Assets			5.8
Decrease in Other Operating Assets			14.2
Gain (Loss) on Sale of Assets and Asset Impairment Charges			$ 33.6

Certain Balance Sheet Informa_3

Certain Balance Sheet Information (Property, Plant And Equipment) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 2,598,100,000	$ 2,285,200,000
Less: accumulated depreciation and depletion	568,400,000	464,400,000
Property, plant and equipment, net	2,029,700,000	1,820,800,000
Depletion	0	700,000	$ 700,000
Interest Costs Capitalized	5,000,000	2,900,000	700,000
Capital Leases, Balance Sheet, Assets by Major Class, Net	9,700,000	2,100,000
Crestwood Equity Partners LP
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,598,100,000	2,285,200,000
Less: accumulated depreciation and depletion	568,400,000	464,400,000
Property, plant and equipment, net	2,029,700,000	1,820,800,000
Depreciation	123,600,000	135,900,000	154,800,000
Crestwood Equity Partners LP | Gathering systems and pipelines and related assets
Property, Plant and Equipment [Line Items]
Property, plant and equipment	758,600,000	678,000,000
Crestwood Equity Partners LP | Facilities and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,230,700,000	1,141,400,000
Crestwood Equity Partners LP | Buildings, land, rights-of-way, storage rights and easements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	331,700,000	319,100,000
Crestwood Equity Partners LP | Vehicles
Property, Plant and Equipment [Line Items]
Property, plant and equipment	17,900,000	37,300,000
Crestwood Equity Partners LP | Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment	230,800,000	87,500,000
Crestwood Equity Partners LP | Office furniture and fixtures
Property, Plant and Equipment [Line Items]
Property, plant and equipment	28,400,000	21,900,000
CMLP
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,928,200,000	2,615,300,000
Less: accumulated depreciation and depletion	725,900,000	607,800,000
Property, plant and equipment, net	2,202,300,000	2,007,500,000
Depreciation	137,700,000	150,000,000	$ 168,900,000
CMLP | Gathering systems and pipelines and related assets
Property, Plant and Equipment [Line Items]
Property, plant and equipment	901,500,000	820,900,000
CMLP | Facilities and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,415,900,000	1,326,500,000
CMLP | Buildings, land, rights-of-way, storage rights and easements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	335,400,000	322,800,000
CMLP | Vehicles
Property, Plant and Equipment [Line Items]
Property, plant and equipment	16,100,000	35,500,000
CMLP | Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment	230,800,000	87,500,000
CMLP | Office furniture and fixtures
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 28,500,000	$ 22,100,000

Certain Balance Sheet Informa_4

Certain Balance Sheet Information (Intangible Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Finite-Lived Intangible Assets [Line Items]
Less: accumulated amortization	$ 216.5	$ 191.6
Crestwood Equity Partners LP
Finite-Lived Intangible Assets [Line Items]
Amortization of Intangible Assets	43.5	53.7	$ 72.5
Intangible assets, Gross	770.3	788.8
Less: accumulated amortization	216.5	191.6
Total intangible assets, net	553.8	597.2
Crestwood Equity Partners LP | Customer accounts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	438.9	438.9
Less: accumulated amortization	112.1	89.8
Crestwood Equity Partners LP | Gathering systems and pipelines and related assets
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	325.2	325.2
Less: accumulated amortization	100.8	82
Crestwood Equity Partners LP | Trademarks
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	6.2	24.7
Less: accumulated amortization	3.6	19.8
CMLP
Finite-Lived Intangible Assets [Line Items]
Amortization of Intangible Assets	42.1	50.6	$ 69.3
Intangible assets, Gross	770.3	773.3
Less: accumulated amortization	216.5	177.6
Total intangible assets, net	553.8	595.7
CMLP | Customer accounts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	438.9	438.9
Less: accumulated amortization	112.1	89.8
CMLP | Gathering systems and pipelines and related assets
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	325.2	325.2
CMLP | Acquired storage contracts
Finite-Lived Intangible Assets [Line Items]
Less: accumulated amortization	3.6	5.8
CMLP | Trademarks
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	6.2	9.2
Less: accumulated amortization	$ 100.8	$ 82

Certain Balance Sheet Informa_5

Certain Balance Sheet Information (Amortization and Interest Expense, Fiscal Year Maturity) (Details) $ in Millions	Dec. 31, 2018USD ($)
Finite-Lived Intangible Assets [Line Items]
2,019	$ 41.7
2,020	41.7
2,021	41.7
2,022	41.7
2,023	$ 37.7

Certain Balance Sheet Informa_6

Certain Balance Sheet Information (Accrued Expenses and Other Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses and other liabilities	$ 112.4	$ 105.9
CMLP
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	63.7	55.5
Accrued property taxes	2.6	4.8
Income tax payable	0.3	0.3
Interest payable	19.8	20.3
Accrued additions to property, plant and equipment	10.5	22.2
Capital leases	2.4	1
Deferred revenue	12	0.6
Accrued expenses and other liabilities	111.3	104.7
Crestwood Equity Partners LP
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	64.8	56.6
Accrued property taxes	2.6	4.8
Income tax payable	0.3	0.3
Interest payable	19.8	20.3
Accrued additions to property, plant and equipment	10.5	22.3
Capital leases	2.4	1
Deferred revenue	12	0.6
Accrued expenses and other liabilities	$ 112.4	$ 105.9
Jackalope Gas Gathering Services, LLC
Accrued Expenses and Other Liabilities [Line Items]
Equity method ownership percentage	50.00%
Jackalope Gas Gathering Services, LLC
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	$ 16.2

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Net asset retirement obligation at January 1	$ 27.5	$ 27.8
Liabilities incurred	0.7	0
Liabilities settled	(2.2)	(1.2)
Accretion expense	(1.6)	(1.4)
Change in estimate	0	(0.5)
Net asset retirement obligation at December 31	$ 27.6	$ 27.5

Investments in Unconsolidated_3

Investments in Unconsolidated Affiliates Table (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Oct. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates		$ 1,188.2	$ 1,183
Earnings from unconsolidated affiliates, net		53.3	47.8	$ 31.5
Proceeds from Equity Method Investment, Distribution		103	107.6	53.9
Payments to Acquire Equity Method Investments Cash and Noncash Consideration			127.4
Payments to Acquire Equity Method Investments		64.4	58	12.4
Equity Method Investment, Summarized Financial Information, Current Assets		127.1	136.4
Equity Method Investment, Summarized Financial Information, Noncurrent Assets		2,755.7	2,566.5
Equity Method Investment, Summarized Financial Information, Current Liabilities		38.4	60.4
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities		225.2	95
Equity Method Investment Summarized Financial Information, Equity		2,619.2	2,547.5
Equity Method Investment, Summarized Financial Information, Revenue		370.5	350.4	226.9
Equity Method Investment Summarized Financial Information Operating Expenses		242.1	221.3	158
Equity Method Investment, Summarized Financial Information, Net Income (Loss)		133.4	130	68.8
Goodwill impairment		$ 0	38.8	162.6
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage		50.00%
Investments in unconsolidated affiliates		$ 830.4	849.8
Earnings from unconsolidated affiliates, net		29.3	25.3	15.9
Proceeds from Equity Method Investment, Distribution		48.7	47.3	16
Payments to Acquire Equity Method Investments		0	0.8	0
Equity Method Investment, Summarized Financial Information, Current Assets		50.1	55.1
Equity Method Investment, Summarized Financial Information, Noncurrent Assets		1,725.1	1,765.4
Equity Method Investment, Summarized Financial Information, Current Liabilities		4.2	7
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities		0.9	1.4
Equity Method Investment Summarized Financial Information, Equity		1,770.1	1,812.1
Equity Method Investment, Summarized Financial Information, Revenue		171.4	168.6	99.3
Equity Method Investment Summarized Financial Information Operating Expenses		79.3	77.7	44.1
Equity Method Investment, Summarized Financial Information, Net Income (Loss)		92.1	91.1	55.3
Difference between carrying amount and underlying equity		51.3
Crestwood Permian Basin LLC
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Summarized Financial Information, Revenue		82.2	87.3	11.5
Equity Method Investment Summarized Financial Information Operating Expenses		81.3	74.1	10.9
Equity Method Investment, Summarized Financial Information, Net Income (Loss)		$ 5.7	14.1	0.6
Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage		50.00%
Investments in unconsolidated affiliates		$ 210.2	184.9
Earnings from unconsolidated affiliates, net		18.1	10.5	20.8
Proceeds from Equity Method Investment, Distribution		32.4	26.3	27.4
Equity Method Investment, Summarized Financial Information, Revenue		116.9	94.5	116.1
Equity Method Investment Summarized Financial Information Operating Expenses		81.5	69.5	103
Equity Method Investment, Summarized Financial Information, Net Income (Loss)		35.6	24.8	12.9
Difference between carrying amount and underlying equity		0.4
Amortization		0.1	0.1	0.1
Other Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Summarized Financial Information, Current Assets		59.3	43.7
Equity Method Investment, Summarized Financial Information, Noncurrent Assets		658	597.8
Equity Method Investment, Summarized Financial Information, Current Liabilities		17.4	20
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities		129.6	91.8
Equity Method Investment Summarized Financial Information, Equity		$ 570.3	529.7
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage		50.00%
Investments in unconsolidated affiliates		$ 104.3	102
Earnings from unconsolidated affiliates, net		4.4	8.4	(0.5)
Proceeds from Equity Method Investment, Distribution	$ 18.9	14.7	23.4	0
Payments to Acquire Equity Method Investments Cash and Noncash Consideration		12.6	117.5
Payments to Acquire Equity Method Investments				0
Equity Method Investment, Summarized Financial Information, Current Assets		17.7	37.6
Equity Method Investment, Summarized Financial Information, Noncurrent Assets		372.6	203.3
Equity Method Investment, Summarized Financial Information, Current Liabilities		16.8	33.4
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities		94.7	1.8
Equity Method Investment Summarized Financial Information, Equity		278.8	205.7
Difference between carrying amount and underlying equity		$ 8.9
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage		50.01%
Investments in unconsolidated affiliates		$ 35	37.8
Earnings from unconsolidated affiliates, net		0	2.2	(0.3)
Proceeds from Equity Method Investment, Distribution		5.3	9	8.5
Payments to Acquire Equity Method Investments		2.5	5.6	11
Difference between carrying amount and underlying equity		25.3
Amortization		$ 1.3	1.3	1.3
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage		50.01%
Investments in unconsolidated affiliates		$ 8.3	8.5
Earnings from unconsolidated affiliates, net		1.5	1.4	(4.4)
Proceeds from Equity Method Investment, Distribution		1.9	1.6	2
Payments to Acquire Equity Method Investments		0.2	0	0
Difference between carrying amount and underlying equity		5.9
Amortization		$ 0.5	$ 0.6	1.6
Goodwill impairment				$ 5.8

Investments in Unconsolidated_4

Investments in Unconsolidated Affiliates - Narrative (Details) - USD ($) $ in Millions	Jul. 01, 2018	Jan. 01, 2018	Jun. 21, 2017	Feb. 28, 2019	Jan. 31, 2019	Oct. 31, 2017	Jun. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments								$ 64.4	$ 58	$ 12.4
Investments in unconsolidated affiliates								1,188.2	1,183
Loss on contingent consideration								0	57	0
Earnings from unconsolidated affiliates, net								53.3	47.8	31.5
Net proceeds from sale of assets								79.5	225.2	972.7
Payments to Acquire Property, Plant, and Equipment								305.5	188.4	100.7
Contribution of Property			$ 69
Proceeds from Equity Method Investment, Distribution								103	107.6	53.9
Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates								210.2	184.9
Earnings from unconsolidated affiliates, net								18.1	10.5	20.8
Difference between carrying amount and underlying equity								0.4
Amortization								$ 0.1	0.1	0.1
Equity method ownership percentage								50.00%
Proceeds from Equity Method Investment, Distribution								$ 32.4	26.3	27.4
Jackalope Gas Gathering Services, LLC | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution				$ 11.6
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments								2.5	5.6	11
Investments in unconsolidated affiliates								35	37.8
Earnings from unconsolidated affiliates, net								0	2.2	(0.3)
Difference between carrying amount and underlying equity								25.3
Amortization								$ 1.3	1.3	1.3
Equity method ownership percentage								50.01%
Proceeds from Equity Method Investment, Distribution								$ 5.3	9	8.5
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments								0.2	0	0
Investments in unconsolidated affiliates								8.3	8.5
Earnings from unconsolidated affiliates, net								1.5	1.4	(4.4)
Difference between carrying amount and underlying equity								5.9
Amortization								$ 0.5	0.6	1.6
Equity method ownership percentage								50.01%
Proceeds from Equity Method Investment, Distribution								$ 1.9	1.6	2
Crestwood Permian Basin Holdings
Schedule of Equity Method Investments [Line Items]
Percentage of Available Cash Distributed								100.00%
Crestwood Permian Basin Holdings | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution					$ 2.3
Crestwood Permian Basin LLC
Schedule of Equity Method Investments [Line Items]
Net proceeds from sale of assets						$ 37.9
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Percentage of Available Cash Distributed	40.00%							40.00%
Payments to Acquire Equity Method Investments								$ 0	0.8	0
Investments in unconsolidated affiliates								830.4	849.8
Contingent consideration, noncurrent liability								57	57
Earnings from unconsolidated affiliates, net								29.3	25.3	15.9
Difference between carrying amount and underlying equity								$ 51.3
Net proceeds from sale of assets										3
Equity method ownership percentage								50.00%
Proceeds from Equity Method Investment, Distribution								$ 48.7	47.3	16
Stagecoach Gas Services LLC | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution					$ 13
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments										0
Investments in unconsolidated affiliates								104.3	102
Earnings from unconsolidated affiliates, net								4.4	8.4	(0.5)
Difference between carrying amount and underlying equity								$ 8.9
Equity method ownership percentage								50.00%
Proceeds from Equity Method Investment, Distribution						$ 18.9		$ 14.7	23.4	$ 0
Crestwood Permian Basin LLC
Schedule of Equity Method Investments [Line Items]
Equity Interest										100.00%
Crestwood Niobrara LLC | Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments								49.1	3.5	$ 1.4
Crestwood Equity Partners LP | Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage										50.00%
SWEPI LP | Crestwood Permian Basin LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage						50.00%
Estimated Cost to Build								180
Payments to Acquire Property, Plant, and Equipment								$ 145.6
Crestwood New Mexico Pipeline LLC [Member] | Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Equity Interest			100.00%
Twin Eagle Powder River Basin, LLC | Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage								50.00%
First Reserve Management, L.P. | Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Capital Commitment to Acquire Equity Method Investment			$ 151
CEGP | Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Percentage of Available Cash Distributed							35.00%	60.00%
Net proceeds from sale of assets										$ 975
CMLP
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments								$ 64.4	58	12.4
Investments in unconsolidated affiliates								1,188.2	1,183
Loss on contingent consideration								0	57	0
Earnings from unconsolidated affiliates, net								53.3	47.8	31.5
Net proceeds from sale of assets								79.5	225.2	972.7
Payments to Acquire Property, Plant, and Equipment								$ 305.5	$ 188.4	100.7
CMLP | Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage								50.01%
CMLP | Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Deconsolidation, Gain (Loss), Amount										$ 32.4
Equity method ownership percentage										50.00%
Williams Partners LP | Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Percentage of voting interests acquired								50.00%
Brookfield Infrastructure Group | Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage								49.99%
Accounting Standards Update 2014-09 | Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Adoption, Quantification		$ 9.5
New Accounting Pronouncement, Equity Earnings Decrease								$ 9.7

Risk Management (Notional Amoun

Risk Management (Notional Amounts and Terms of Company's Derivative Financial Instruments) (Details) bbl in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)bbl	Dec. 31, 2017USD ($)bbl	Dec. 31, 2016USD ($)
Derivative [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Revenue	$ 343.3	$ 234.1	$ 162.9
Collateral posted for commodity derivative instruments	14.2	3.7
Commodity Contract With Credit Contingent Features [Member]
Derivative [Line Items]
Aggregate fair value of commodity derivative instruments	2.2	28.9
NYMEX Derivative Liability [Member]
Derivative [Line Items]
Derivative Asset	(9.4)	27.2
Commodity Contract
Derivative [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	29.6	(31.2)	$ (7.8)
Collateral posted for commodity derivative instruments	0.1	0.1
NYMEX Margin Deposit [Member]
Derivative [Line Items]
NYMEX margin deposit	$ 21.7	$ 5.6
Propane, crude and heating oil (MMBbls) | Fixed Price Payor
Derivative [Line Items]
Propane, crude and heating oil (MMBbls) | bbl	27.8	15.3
Propane, crude and heating oil (MMBbls) | Fixed Price Receiver
Derivative [Line Items]
Propane, crude and heating oil (MMBbls) | bbl	30.1	17.5
Natural Gas [Member] | Fixed Price Payor
Derivative [Line Items]
Propane, crude and heating oil (MMBbls) | bbl	1,800	780
Natural Gas [Member] | Fixed Price Receiver
Derivative [Line Items]
Propane, crude and heating oil (MMBbls) | bbl	1,800	660

Risk Management (Narrative) (De

Risk Management (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Derivative [Line Items]
Collateral posted for commodity derivative instruments	$ 14.2	$ 3.7
Price Risk Contracts | Maximum
Derivative [Line Items]
Remaining maturity	36 months
Percent of contracts expiring in next twelve months	82.00%
Commodity Contract
Derivative [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ 29.6	(31.2)	$ (7.8)
Collateral posted for commodity derivative instruments	$ 0.1	$ 0.1

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule of Carrying Values and Estimated Fair Values of Senior Notes) (Details) - CMLP - Crestwood Midstream Senior Notes - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Senior Notes, 2023
Debt Instrument [Line Items]
Carrying Amount	$ 693.6	$ 692.1
Debt Instrument, Fair Value Disclosure	668.1	728.8
Senior Notes, 2025
Debt Instrument [Line Items]
Carrying Amount	493.4	492.3
Debt Instrument, Fair Value Disclosure	$ 466.2	$ 517.9

Fair Value Measurements (Assets

Fair Value Measurements (Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Assets, Fair Value Disclosure [Abstract]
Assets from price risk management	$ 173.1	$ 103.3
SPH units	2.8	3.5
Assets, Fair Value Disclosure, Excluding Netting Adjustments	175.9	106.8
Netting Agreements	(140.3)	(74.6)
Derivative Asset, Fair Value of Collateral	1.9	(21.5)
Assets from price risk management, Total	34.7	7.2
Total assets at fair value	37.5	10.7
Liabilities, Fair Value Disclosure [Abstract]
Liabilities from price risk management	151.7	119.6
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	151.7	119.6
Netting Agreements	(140.3)	(74.6)
Derivative Liability, Fair Value of Collateral	(5.6)	3.9
Liabilities from price risk management, Total	5.8	48.9
Total liabilities at fair value		48.9
Level 1
Assets, Fair Value Disclosure [Abstract]
Assets from price risk management	12.4	1.1
SPH units	2.8	3.5
Assets, Fair Value Disclosure, Excluding Netting Adjustments	15.2	4.6
Liabilities, Fair Value Disclosure [Abstract]
Liabilities from price risk management	7	1.4
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	7	1.4
Level 2
Assets, Fair Value Disclosure [Abstract]
Assets from price risk management	160.7	102.2
SPH units	0	0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	160.7	102.2
Liabilities, Fair Value Disclosure [Abstract]
Liabilities from price risk management	144.7	118.2
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	144.7	118.2
Level 3
Assets, Fair Value Disclosure [Abstract]
Assets from price risk management	0	0
SPH units	0	0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	0	0
Liabilities, Fair Value Disclosure [Abstract]
Liabilities from price risk management	0	0
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	$ 0	$ 0

Long-Term Debt (Components Of L

Long-Term Debt (Components Of Long-Term Debt) (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Mar. 31, 2017
Debt Instrument [Line Items]
Debt Issuance Costs, Net	$ 26.4	$ 28.4
Less: current portion	0.9	0.9
Total long-term debt	1,752.4	1,491.3
Crestwood Midstream Revolver | Revolving Credit Facility
Debt Instrument [Line Items]
Credit agreement outstanding carrying value	578.2	318.2
Senior Notes, 2025 | Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Carrying Amount			$ 500
CMLP
Debt Instrument [Line Items]
Obligations under noncompetition agreements and notes to former owners of businesses acquired	1.5	2.4
Debt, Long-term and Short-term, Combined Amount	1,753.3	1,492.2
Less: current portion	0.9	0.9
Total long-term debt	1,752.4	1,491.3
CMLP | Senior Notes, 2023 | Crestwood Midstream 2022 senior unsecured notes
Debt Instrument [Line Items]
Carrying Amount	700	700
CMLP | Senior Notes, 2025 | Crestwood Midstream 2022 senior unsecured notes
Debt Instrument [Line Items]
Carrying Amount	$ 500	$ 500

Long-Term Debt (Narrative) (Det

Long-Term Debt (Narrative) (Detail)	1 Months Ended		9 Months Ended	12 Months Ended
	Mar. 31, 2017USD ($)	Jun. 30, 2016USD ($)	Sep. 30, 2016USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Debt Instrument [Line Items]
Amount of Restricted Net Assets for Consolidated and Unconsolidated Subsidiaries				$ 2,028,200,000
Gains (Losses) on Extinguishment of Debt			$ 10,000,000	(900,000)	$ (37,700,000)	$ 10,000,000
Debt Issuance Costs, Net				26,400,000	28,400,000
Repayments of Senior Debt		$ 312,900,000
CMLP
Debt Instrument [Line Items]
Gains (Losses) on Extinguishment of Debt				$ (900,000)	(37,700,000)	$ 10,000,000
Revolving Loan Facility | CMLP
Debt Instrument [Line Items]
Debt Instrument, Term				5 years
Credit agreement outstanding carrying value				$ 1,250,000,000	1,500,000,000
Crestwood Midstream Revolver
Debt Instrument [Line Items]
Gains (Losses) on Extinguishment of Debt				$ 900,000
Senior Notes, 2023 | Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage				6.25%
Senior Notes, 2023 | Crestwood Midstream 2022 senior unsecured notes | CMLP
Debt Instrument [Line Items]
Carrying amount				$ 700,000,000	700,000,000
Senior Notes, 2025 | Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Carrying amount	$ 500,000,000
Interest rate, stated percentage	5.75%
Senior Notes, 2025 | Crestwood Midstream 2019 Senior Notes | CMLP
Debt Instrument [Line Items]
Proceeds from Issuance of Debt	$ 492,000,000
Senior Notes, 2025 | Crestwood Midstream 2022 senior unsecured notes | CMLP
Debt Instrument [Line Items]
Carrying amount				500,000,000	500,000,000
Crestwood Midstream Credit Facility
Debt Instrument [Line Items]
Line of Credit Facility, Additional Potential Capacity				350,000,000
Line of Credit Facility, Current Borrowing Capacity				350,000,000
Crestwood Midstream Credit Facility | Minimum
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Amount				0.0025
Crestwood Midstream Credit Facility | Maximum
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Amount				$ 0.0045
Senior Notes, 2022
Debt Instrument [Line Items]
Debt Issuance Costs, Net					6,800,000
Repayments of Senior Debt					457,800,000
Senior Notes, 2022 | Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Interest Paid, Including Capitalized Interest, Operating and Investing Activities		2,600,000			1,000,000
Extinguishment of Debt, Amount		163,600,000
Senior Notes, 2020
Debt Instrument [Line Items]
Repayments of Senior Debt					349,900,000
Senior Notes, 2020 | Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Interest Paid, Including Capitalized Interest, Operating and Investing Activities		4,500,000			5,100,000
Extinguishment of Debt, Amount		$ 161,200,000
Crestwood Midstream Revolver
Debt Instrument [Line Items]
Consolidated leverage ratio, maximum				5.50
Crestwood Midstream Revolver | Revolving Credit Facility
Debt Instrument [Line Items]
Credit agreement outstanding carrying value				$ 578,200,000	318,200,000
Letters of credit outstanding				$ 68,000,000	$ 52,200,000
Total funded debt to consolidated EBITDA				4.25
Consolidated EBITDA to consolidated interest expense				4.4
Senior Secured Leverage Ratio				1.38
Weighted average interest rate				4.79%	4.11%
Unused borrowing capacity				$ 524,000,000
Interest coverage ratio, minimum				2.50
Senior Secured Leverage Ratio, maximum				3.75
Crestwood Midstream Revolver | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Weighted average interest rate				4.63%	3.94%
Crestwood Midstream Revolver | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Weighted average interest rate				6.75%	6.00%
Crestwood Midstream Revolver | Bridge Loan
Debt Instrument [Line Items]
Credit agreement outstanding carrying value				$ 25,000,000
Obligations Under Noncompetition Agreements And Notes To Former Owners Of Businesses Acquired | CMLP
Debt Instrument [Line Items]
Total payments due				1,700,000	$ 2,700,000
Obligations under noncompete agreements, unamortized discount				$ 200,000	$ 300,000
Obligations Under Noncompetition Agreements And Notes To Former Owners Of Businesses Acquired | Minimum | CMLP
Debt Instrument [Line Items]
Inputed interest				5.02%
Obligations Under Noncompetition Agreements And Notes To Former Owners Of Businesses Acquired | Maximum | CMLP
Debt Instrument [Line Items]
Inputed interest				6.75%
Federal Funds Rate | Revolving Credit Facility | Crestwood Midstream Revolver
Debt Instrument [Line Items]
Variable interest rate				0.50%
Eurodollar [Member] | Revolving Credit Facility | Crestwood Midstream Credit Facility | Minimum
Debt Instrument [Line Items]
Variable interest rate				1.50%
Eurodollar [Member] | Revolving Credit Facility | Crestwood Midstream Credit Facility | Maximum
Debt Instrument [Line Items]
Variable interest rate				2.50%
Eurodollar [Member] | Revolving Credit Facility | Crestwood Midstream Revolver
Debt Instrument [Line Items]
Variable interest rate				1.00%
Eurodollar [Member] | Revolving Credit Facility | Crestwood Midstream Revolver | Minimum
Debt Instrument [Line Items]
Variable interest rate				0.50%
Eurodollar [Member] | Revolving Credit Facility | Crestwood Midstream Revolver | Maximum
Debt Instrument [Line Items]
Variable interest rate				1.50%
Tres Palacios Holdings LLC
Debt Instrument [Line Items]
Equity method ownership percentage				50.01%
Tres Palacios Holdings LLC | CMLP
Debt Instrument [Line Items]
Equity method ownership percentage				50.01%
Financial Guarantee [Member]
Debt Instrument [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted				$ 497,000,000
Interest rate, stated percentage				7.50%

Long-Term Debt (Maturities of L

Long-Term Debt (Maturities of Long Term Debt) (Details) - CMLP $ in Millions	Dec. 31, 2018USD ($)
Debt Instrument [Line Items]
2,019	$ 0.9
2,020	0.2
2,021	0.2
2,022	0.2
2,023	1,278.2
Thereafter	500
Total debt	$ 1,779.7

Earnings Per Limited Partner _3

Earnings Per Limited Partner Unit (Schedule of Reconciliation of Earnings Per Share) (Details) - shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Preferred Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of earnings per share	7,125,744	7,007,917	6,433,127
Subordinated units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of earnings per share	438,789	438,789	438,789
Performance Shares
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of earnings per share	365,997	316,980	0
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	6,526,495	7,146,663	7,548,624

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Deferred:
Total deferred	$ 0.7	$ 2.1	$ 3.1
(Provision) benefit for income taxes	(0.1)	0.8	(0.3)
Crestwood Equity Partners LP
Current:
Federal	(0.5)	(1.1)	(3.2)
State	(0.3)	(0.2)	(0.2)
Total current	(0.8)	(1.3)	(3.4)
Deferred:
Federal	0.5	2.1	3
State	0.2	0	0.1
Total deferred	0.7	2.1	3.1
(Provision) benefit for income taxes	(0.1)	0.8	(0.3)
Deferred tax asset:
Basis difference in stock of company	0.2	0.2
Total deferred tax asset	0.2	0.2
Deferred Tax Liabilities, Other	2.8	3.5
Deferred tax liability:
Deferred Tax Liabilities, Gross	(2.8)	(3.5)
Total deferred tax liability	(2.6)	(3.3)
CMLP
Current:
Federal	0.1	0	0
State	(0.2)	0	0.2
Total current	(0.1)	0	0.2
Deferred:
Federal	0	0	0
State	0.1	0	(0.2)
Total deferred	0.1	0	(0.2)
(Provision) benefit for income taxes	0	0	$ 0
Deferred tax asset:
Basis difference in stock of company	0	0
Total deferred tax asset	0	0
Deferred Tax Liabilities, Other	0.6	0.7
Deferred tax liability:
Deferred Tax Liabilities, Gross	(0.6)	(0.7)
Total deferred tax liability	$ (0.6)	$ (0.7)

Partners' Capital (Schedule of

Partners' Capital (Schedule of Issuance of Units) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Partners' Capital [Abstract]
Partners' Capital Account, Units, Sold in Public Offering	0	633,271
Proceeds from Issuance or Sale of Equity		$ 15.2
Units	71,659,385	70,721,563

Partners' Capital (Narrative) (

Partners' Capital (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Feb. 14, 2019	Feb. 07, 2019	Nov. 14, 2018	Nov. 07, 2018	Aug. 14, 2018	Aug. 07, 2018	May 15, 2018	May 08, 2018	Feb. 14, 2018	Feb. 07, 2018	Nov. 14, 2017	Nov. 07, 2017	Aug. 14, 2017	Aug. 07, 2017	May 15, 2017	May 08, 2017	Feb. 14, 2017	Feb. 07, 2017	Nov. 14, 2016	Nov. 07, 2016	Aug. 12, 2016	Aug. 05, 2016	May 13, 2016	May 06, 2016	Feb. 12, 2016	Feb. 05, 2016	Jan. 31, 2019	Dec. 31, 2017	Nov. 30, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Mar. 31, 2018
Distribution Made to Member or Limited Partner [Line Items]
Distribution to limited partner, distribution date			Nov. 14, 2018		Aug. 14, 2018		May 15, 2018		Feb. 14, 2018		Nov. 14, 2017		Aug. 14, 2017		May 15, 2017		Feb. 14, 2017		Nov. 14, 2016		Aug. 12, 2016		May 13, 2016		Feb. 12, 2016
Maximum Period For Distribution Of Available Cash																														45 days
Per unit rate, in dollars per unit			$ 0.60		$ 0.60		$ 0.60		$ 0.6		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 1.3750
Distributions to partners																														$ (170.8)	$ (167.6)	$ (219.8)
Payments to Acquire Equity Method Investments																														64.4	58	12.4
Loss on contingent consideration																														0	$ (57)	$ 0
Distribution made to limited partners																															4,724,030	5,815,170
Distributions paid to non-controlling partners																														$ 9.9	$ 15.2	$ 15.2
Limited partners' units, issued																												70,721,563		71,659,385	70,721,563
Dividends, Paid-in-kind																														$ 43.1	$ 53
Issuance of preferred equity of subsidiary																															$ 0
Preferred units, outstanding																												71,257,445		71,257,445	71,257,445		71,257,445
Preferred units, issued																												71,257,445		71,257,445	71,257,445
Equity Offering Program Authorized Amount																														$ 250
Equity Distribution Program Management Fee Percentage																														2.00%
Payments of Stock Issuance Costs																															$ 0.3
Partners' Capital Account, Units, Sold in Public Offering																														0	633,271
Proceeds from Issuance or Sale of Equity																															$ 15.2
Distributions to preferred unitholders																													$ 15	$ 60.1	15	0
Distribution to limited partner, record date				Nov. 7, 2018		Aug. 7, 2018		May 8, 2018		Feb. 7, 2018		Nov. 7, 2017		Aug. 7, 2017		May 8, 2017		Feb. 7, 2017		Nov. 7, 2016		Aug. 5, 2016		May 6, 2016		Feb. 5, 2016
Payments for Repurchase of Redeemable Noncontrolling Interest																												$ 202.7		0	202.7	0
Proceeds from Noncontrolling Interests																												$ 175		$ 0	175	0
Preferred Units, Class A
Distribution Made to Member or Limited Partner [Line Items]
Partners' Capital Account, Private Placement of Units, Price Per Unit																														$ 9.13
Subsequent Event
Distribution Made to Member or Limited Partner [Line Items]
Distributions to preferred unitholders	$ 15
Crestwood Equity Partners LP
Distribution Made to Member or Limited Partner [Line Items]
Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest																														99.90%
Crestwood Niobrara LLC | Cash distribution
Distribution Made to Member or Limited Partner [Line Items]
Distributions paid to non-controlling partners																														$ 9.9	15.2	15.2
Crestwood Niobrara LLC | Subsequent Event | Cash distribution
Distribution Made to Member or Limited Partner [Line Items]
Distributions paid to non-controlling partners																											$ 3.3
Crestwood Gas Services GP, LLC
Distribution Made to Member or Limited Partner [Line Items]
Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest																														0.10%
CMLP
Distribution Made to Member or Limited Partner [Line Items]
Distributions to partners																														$ (238.4)	(174)	(227.6)
Payments to Acquire Equity Method Investments																														64.4	58	12.4
Loss on contingent consideration																														0	(57)	0
Distributions paid to non-controlling partners																														9.9	15.2	15.2
Issuance of preferred equity of subsidiary																															175
Distribution Made to General Partner, Cash Distributions Paid																														238.4	174	227.6
Payments for Repurchase of Redeemable Noncontrolling Interest																														0	202.7	0
Proceeds from Noncontrolling Interests																														0	175	0
Tres Palacios Holdings LLC
Distribution Made to Member or Limited Partner [Line Items]
Payments to Acquire Equity Method Investments																														$ 2.5	5.6	11
Equity method ownership percentage																														50.01%
Tres Palacios Holdings LLC | CMLP
Distribution Made to Member or Limited Partner [Line Items]
Equity method ownership percentage																														50.01%
Jackalope Gas Gathering Services, LLC
Distribution Made to Member or Limited Partner [Line Items]
Equity method ownership percentage																														50.00%
Jackalope Gas Gathering Services, LLC | Crestwood Niobrara LLC
Distribution Made to Member or Limited Partner [Line Items]
Payments to Acquire Equity Method Investments																														$ 49.1	3.5	$ 1.4
Cash distribution | Subsequent Event
Distribution Made to Member or Limited Partner [Line Items]
Distribution to limited partner, distribution date	Feb. 14, 2019
Distribution declared per limited partner unit	$ 0.600
Distribution to limited partner, record date		Feb. 7, 2019
Preferred Partner
Distribution Made to Member or Limited Partner [Line Items]
Partners' Capital, Distribution Amount Per Share																														$ 0.2567
Partners' Capital, Contingent Distribution Amount Per Share																														$ 0.2111
Partner's Capital, Unpaid Distribution, Accrual Percentage																														2.8125%
Subordinated Unit | Limited Partners
Distribution Made to Member or Limited Partner [Line Items]
Limited partners' units, issued																																438,789
Partners' Capital Account, Units, Cash Distribution Threshold, Quarterly Distribution																														$ 1.30
Partners' Capital Account, Units, Conversion Threshold, Cumulative Distribution																														$ 5.20
Non-Controlling Partners
Distribution Made to Member or Limited Partner [Line Items]
Contribution from issuance of units																														$ 0	0
Issuance of preferred equity of subsidiary																															175
Non-Controlling Partners | CMLP
Distribution Made to Member or Limited Partner [Line Items]
Issuance of preferred equity of subsidiary																															$ 175

Partners' Capital (Schedule o_2

Partners' Capital (Schedule of Partnership Distributions) (Details) - USD ($) $ / shares in Units, $ in Millions

Feb. 14, 2019

Feb. 07, 2019

Nov. 14, 2018

Nov. 07, 2018

Aug. 14, 2018

Aug. 07, 2018

May 15, 2018

May 08, 2018

Feb. 14, 2018

Feb. 07, 2018

Nov. 14, 2017

Nov. 07, 2017

Aug. 14, 2017

Aug. 07, 2017

May 15, 2017

May 08, 2017

Feb. 14, 2017

Feb. 07, 2017

Nov. 14, 2016

Nov. 07, 2016

Aug. 12, 2016

Aug. 05, 2016

May 13, 2016

May 06, 2016

Feb. 12, 2016

Feb. 05, 2016

Dec. 31, 2018

Dec. 31, 2017

Dec. 31, 2016

Disclosure Partners Capital Summary Of Quarterly Distributions Of Available Cash [Abstract]

Distribution to limited partner, record date

Nov. 7, 2018

Aug. 7, 2018

May 8, 2018

Feb. 7, 2018

Nov. 7, 2017

Aug. 7, 2017

May 8, 2017

Feb. 7, 2017

Nov. 7, 2016

Aug. 5, 2016

May 6, 2016

Feb. 5, 2016

Distribution to limited partner, distribution date

Nov. 14, 2018

Aug. 14, 2018

May 15, 2018

Feb. 14, 2018

Nov. 14, 2017

Aug. 14, 2017

May 15, 2017

Feb. 14, 2017

Nov. 14, 2016

Aug. 12, 2016

May 13, 2016

Feb. 12, 2016

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.60

$ 0.60

$ 0.60

$ 0.6

$ 0.60

$ 0.60

$ 0.60

$ 0.60

$ 0.60

$ 0.60

$ 0.60

$ 1.3750

Distribution amount

$ 42.7

$ 42.7

$ 42.7

$ 42.7

$ 42.2

$ 41.8

$ 41.8

$ 41.8

$ 41.4

$ 41.4

$ 41.4

$ 95.6

$ 170.8

$ 167.6

$ 219.8

Cash distribution | Subsequent Event

Disclosure Partners Capital Summary Of Quarterly Distributions Of Available Cash [Abstract]

Distribution to limited partner, record date

Feb. 7, 2019

Distribution to limited partner, distribution date

Feb. 14, 2019

Distribution declared per limited partner unit

$ 0.600

Partners' Capital Net Income (L

Partners' Capital Net Income (Loss) Attributable to NonControlling Partners (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Limited Partners' Capital Account [Line Items]
Net income (loss) attributable to non-controlling partners in subsidiary	$ 16.2	$ 25.3	$ 24.2
CMLP
Limited Partners' Capital Account [Line Items]
Net income (loss) attributable to non-controlling partners in subsidiary	16.2	25.3	24.2
Crestwood Niobrara LLC
Limited Partners' Capital Account [Line Items]
Net income (loss) attributable to non-controlling partners in subsidiary	$ 16.2	$ 25.3	$ 24.2

Equity Plans (Schedule of Phant

Equity Plans (Schedule of Phantom and Restricted Unit Activity) (Details) - Crestwood Long-Term Incentive Plan - $ / shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Unvested units - December 31, units	1,830,096	1,292,330	466,214
Unvested units - December 31	$ 25.21	$ 24.67	$ 69.80
Unvested units - December 31, units	2,187,970	1,830,096	1,292,330
Unvested units - December 31	$ 24.78	$ 25.21	$ 24.67
Restricted units
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Granted, units	1,144,017	919,411	1,067,535
Granted	$ 25.80	$ 25.69	$ 14.58
Vested, units	(617,807)	(607,115)	(193,295)
Vested	$ 23.73	$ 28	$ 76.82
Canceled, units	(53,530)	(140,137)	(65,591)
Canceled	$ 23.36	$ 23.73	$ 25.13
Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Granted, units	901	405,620
Granted	$ 25.60	$ 30.21
Vested, units	(11,772)	(31,106)
Vested	$ 28.87	$ 30.27
Canceled, units	(5,870)	(24,756)
Canceled	$ 30.45	$ 30.45
Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Granted, units	7,750	15,849	17,467
Granted	$ 26.10	$ 25.02	$ 15.54
Vested, units	(105,809)
Vested	$ 49.45
Canceled, units	(6)
Canceled	$ 49.45

Equity Plans (Narrative) (Detai

Equity Plans (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Feb. 11, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 24,300,000	$ 22,400,000	$ 16,000,000
Employer matching contribution, percent	6.00%
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Percent	10.00%
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Amount	$ 25,000
Common Stock, Shares Authorized	1,500,000
Unit Purchase Plan, Shares Purchased Under Plan	$ 0
Crestwood Long-Term Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation costs not yet recognized	$ 28,000,000	$ 23,700,000
Common units to satisfy employee tax withholding obligations	221,576	206,600	57,508
Subsequent Event | Crestwood Long-Term Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares reserved for future issuance				4,036,711
Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance multiplier	50.00%
Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance multiplier	200.00%

Employee Benefit Plan (Details)

Employee Benefit Plan (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Postemployment Benefits [Abstract]
Defined Contribution Plan, Employer Matching Contribution, Percent	90.00%
Defined Benefit Plan, Employee Contributions, Statutory Maximum Per Employee	$ 18,500	$ 18,000	$ 18,000
Defined Contribution Plan Participants Basic Contribution	100.00%
Employer matching contribution, percent	6.00%
Defined Contribution Plan, Requisite Service Period	90 days
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 4,600,000	$ 4,000,000	$ 3,800,000

Commitments and Contingencies_2

Commitments and Contingencies (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)bblRelease	Dec. 31, 2017USD ($)	Sep. 15, 2015USD ($)	May 06, 2015bbl
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency Accrual, at Carrying Value	$ 0.1	$ 2.1
Accrual for Environmental Loss Contingencies	1.8	1.9
Other Growth and Maintenance Contractual Purchase Obligations
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Firm Purchase Commitments	77.2
Commodity
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Firm Purchase Commitments	894
Purchase Obligation, Due in Next Twelve Months	784.3
Crestwood Equity Partners LP
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Self-insurance reserves	11.3	13.6
Self-insurance reserve expected to be paid in next fiscal year	7.5
CMLP
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Self-insurance reserves	9.6	$ 11.6
Self-insurance reserve expected to be paid in next fiscal year	6.2
Maximum
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Estimate of Possible Loss	3.3		$ 1.1
Minimum
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Estimate of Possible Loss	$ 1.8
Fort Berthold Indian Reservation
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Site Contingency, Loss Exposure, Number of Releases of Produced Water | Release	3
Site Contingency, Loss Exposure, Release of Produced Water | bbl	28,000			5,200

Commitments and Contingencies_3

Commitments and Contingencies (Schedule of Future Minimum Lease Payments under Noncancelable Operatng Leases) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating Leases
2,019	$ 22.3
2,020	18.1
2,021	14.4
2,022	9.7
2,023	6
Thereafter	10.7
Total minimum lease payments	81.2
Minimum Lease Payments
2,019	3
2,020	3.3
2,021	3.2
2,022	1.9
2,023	0
Thereafter	0
Total minimum lease payments	11.4
Capital Leases, Interest
2,019	0.6
2,020	0.4
2,021	0.2
2,022	0.1
2,023	0
Thereafter	0
Total minimum lease payments	1.3
Capital Leases, Net Present Value
2,019	2.4
2,020	2.9
2,021	3
2,022	1.8
2,023	0
Thereafter	0
Total minimum lease payments	10.1
Total
2,019	24.7
2,020	21
2,021	17.4
2,022	11.5
2,023	6
Thereafter	10.7
Total minimum lease payments	91.3
Rent expense	$ 13.9	$ 34.2	$ 25.5

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Payments to Acquire Property, Plant, and Equipment	$ 305.5	$ 188.4	$ 100.7
Revenues at CEQP and CMLP	1	1.8	2.6
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	28.7	22.3	8.1
Applied Consultants, Inc. [Member]
Related Party Transaction [Line Items]
Payments to Acquire Property, Plant, and Equipment	7.2	2.5
Crestwood Permian Basin Holdings LLC
Related Party Transaction [Line Items]
Costs of product/services sold at CEQP and CMLP(1)	56.1
Ascent Resources - Utica, LLC [Member]
Related Party Transaction [Line Items]
Costs of product/services sold at CEQP and CMLP(1)	78.6
Affiliated Entity
Related Party Transaction [Line Items]
Revenues at CEQP and CMLP	1	1.8	2.6
Costs of product/services sold at CEQP and CMLP(1)	134.7	15.3	17.7
General and administrative expenses charged by CEQP to CMLP, net(3)	20.7	19.4	13
CMLP
Related Party Transaction [Line Items]
Payments to Acquire Property, Plant, and Equipment	305.5	188.4	100.7
Revenues at CEQP and CMLP	1	1.8	2.6
CMLP | Affiliated Entity
Related Party Transaction [Line Items]
General and administrative expenses charged by CEQP to CMLP, net(3)	3.6	3	3
Related Party Transaction, Due from (to) Related Party [Abstract]
Accounts payable at CEQP	13.6	5
Crestwood Equity Partners LP
Related Party Transaction [Line Items]
Related Party Transaction, (Income) Expenses from Transactions with Related Party	(2.7)	(1.7)	(2.2)
Crestwood Equity Partners LP | Affiliated Entity
Related Party Transaction, Due from (to) Related Party [Abstract]
Accounts receivable at CEQP and CMLP	4.1	7.1
Accounts payable at CEQP	16.1	7.4
Crestwood Long-Term Incentive Plan | CMLP
Related Party Transaction [Line Items]
Allocated share based compensation expense	24.3	22.4	16
Crestwood Long-Term Incentive Plan | Crestwood Holdings
Related Party Transaction [Line Items]
Allocated share based compensation expense	4.2	3.1	3.2
Stagecoach Gas Services LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	7.9	8.4	5
Tres Palacios Holdings LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	3.8	3.5	2.7
Crestwood Permian Basin Holdings
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	15.9	10
Jackalope Gas Gathering Services, LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	$ 1.1	$ 0.4	$ 0.4

Segments (Narrative) (Details)

Segments (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)	Dec. 31, 2018	Dec. 31, 2018segment	Dec. 31, 2018reporting_units	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Revenue, Major Customer [Line Items]
Number of operating segments			3	3
Concentration Risk, Percentage		10.00%			10.00%	10.00%
Crestwood Equity Partners LP
Revenue, Major Customer [Line Items]
Earnings (Losses) Before Interest, Taxes, Depreciation and Amortization from Equity Method Investments	$ 42.3				$ 32.5	$ 29.6

Segments (Reconciliation of Net

Segments (Reconciliation of Net Income (Loss) to EBITDA) (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Net income (loss)		$ 67	$ (166.6)	$ (192.1)
Interest and debt expense, net		(99.2)	(99.4)	(125.1)
(Gain) loss on modification/extinguishment of debt	$ (10)	0.9	37.7	(10)
(Provision) benefit for income taxes		0.1	(0.8)	0.3
Depreciation, amortization and accretion		168.7	191.7	229.6
EBITDA		335.9	161.4	152.9
CMLP
Segment Reporting Information [Line Items]
Net income (loss)		58.6	(175.5)	(197.5)
Interest and debt expense, net		(99.2)	(99.4)	(125.1)
(Gain) loss on modification/extinguishment of debt		0.9	37.7	(10)
(Provision) benefit for income taxes		0	0	0
Depreciation, amortization and accretion		181.4	202.7	240.5
EBITDA		$ 340.1	$ 164.3	$ 158.1

Segments (Summary Of Segment In

Segments (Summary Of Segment Information) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Operating revenues	$ 3,654.1	$ 3,880.9	$ 2,520.5
Intersegment Revenues	0	0	0
Costs of product/services sold	3,129.4	3,374.7	1,925.1
Operations and maintenance	125.8	136	158.1
General and administrative	88.1	96.5	88.2
Loss on long-lived assets, net	(28.6)	(65.6)	(65.6)
Goodwill impairment	0	(38.8)	(162.6)
Loss on contingent consideration	0	(57)	0
Earnings from unconsolidated affiliates, net	53.3	47.8	31.5
Other income, net	0.4	1.3	0.5
EBITDA	335.9	161.4	152.9
Goodwill	138.6	147.6
Assets	4,294.5	4,284.9
Payments to Acquire Property, Plant, and Equipment	305.5	188.4	100.7
CMLP
Segment Reporting Information [Line Items]
Operating revenues	3,654.1	3,880.9	2,520.5
Intersegment Revenues	0	0	0
Costs of product/services sold	3,129.4	3,374.7	1,925.1
Operations and maintenance	125.8	136	155
General and administrative	83.5	93.1	85.6
Loss on long-lived assets, net	(28.6)	(65.6)	(65.6)
Goodwill impairment	0	(38.8)	(162.6)
Loss on contingent consideration	0	(57)	0
Earnings from unconsolidated affiliates, net	53.3	47.8	31.5
Other income, net		0.8
EBITDA	340.1	164.3	158.1
Goodwill	138.6	147.6
Assets	4,462	4,466.3
Payments to Acquire Property, Plant, and Equipment	305.5	188.4	100.7
Gathering systems and pipelines and related assets
Segment Reporting Information [Line Items]
Operating revenues	946.7	1,688.2	1,118.8
Intersegment Revenues	192.4	134.5	108.6
Costs of product/services sold	767	1,480.8	917
Operations and maintenance	71.7	68.4	77
General and administrative	0	0	0
Loss on long-lived assets, net	(3)	(14.4)	(2)
Goodwill impairment		0	(8.6)
Loss on contingent consideration		0
Earnings from unconsolidated affiliates, net	22.5	18.9	20.3
Other income, net	0	0.8	0
EBITDA	319.9	278.8	243.1
Goodwill	45.9	45.9
Assets	2,633.4	2,474.1
Payments to Acquire Property, Plant, and Equipment	294.7	162.7	76.6
Gathering systems and pipelines and related assets | CMLP
Segment Reporting Information [Line Items]
Operating revenues	946.7	1,688.2	1,118.8
Intersegment Revenues	192.4	134.5	108.6
Costs of product/services sold	767	1,480.8	917
Operations and maintenance	71.7	68.4	77
General and administrative	0	0	0
Loss on long-lived assets, net	(3)	(14.4)	(2)
Goodwill impairment		0	(8.6)
Loss on contingent consideration		0
Earnings from unconsolidated affiliates, net	22.5	18.9	20.3
Other income, net		0.8
EBITDA	319.9	278.8	243.1
Goodwill	45.9	45.9
Assets	2,807.1	2,662
Payments to Acquire Property, Plant, and Equipment	294.7	162.7	76.6
Storage and Transportation
Segment Reporting Information [Line Items]
Operating revenues	17.1	37.2	165.3
Intersegment Revenues	10.5	6.7	4.2
Costs of product/services sold	0.2	0.3	5.1
Operations and maintenance	3.3	4.2	21.4
General and administrative	0	0	0
Loss on long-lived assets, net	0	0	(32.2)
Goodwill impairment		0	(44.9)
Loss on contingent consideration		(57)
Earnings from unconsolidated affiliates, net	30.8	28.9	11.2
Other income, net	0	0	0
EBITDA	54.9	11.3	77.1
Goodwill	0	0
Assets	1,004.4	1,040.6
Payments to Acquire Property, Plant, and Equipment	0.6	1.3	3.3
Storage and Transportation | CMLP
Segment Reporting Information [Line Items]
Operating revenues	17.1	37.2	165.3
Intersegment Revenues	10.5	6.7	4.2
Costs of product/services sold	0.2	0.3	5.1
Operations and maintenance	3.3	4.2	18.3
General and administrative	0	0	0
Loss on long-lived assets, net	0	0	(32.2)
Goodwill impairment		0	(44.9)
Loss on contingent consideration		(57)
Earnings from unconsolidated affiliates, net	30.8	28.9	11.2
Other income, net		0
EBITDA	54.9	11.3	80.2
Goodwill	0	0
Assets	1,004.4	1,040.6
Payments to Acquire Property, Plant, and Equipment	0.6	1.3	3.3
Marketing Supply and Logistics
Segment Reporting Information [Line Items]
Operating revenues	2,690.3	2,155.5	1,236.4
Intersegment Revenues	(202.9)	(141.2)	(112.8)
Costs of product/services sold	2,362.2	1,893.6	1,003
Operations and maintenance	50.8	63.4	59.7
General and administrative	0	0	0
Loss on long-lived assets, net	(27.3)	(48.2)	(31.4)
Goodwill impairment		(38.8)	(109.1)
Loss on contingent consideration		0
Earnings from unconsolidated affiliates, net	0	0	0
Other income, net	0	0	0
EBITDA	47.1	(29.7)	(79.6)
Goodwill	92.7	101.7
Assets	612.5	757.1
Payments to Acquire Property, Plant, and Equipment	5.6	17.7	19.1
Marketing Supply and Logistics | CMLP
Segment Reporting Information [Line Items]
Operating revenues	2,690.3	2,155.5	1,236.4
Intersegment Revenues	(202.9)	(141.2)	(112.8)
Costs of product/services sold	2,362.2	1,893.6	1,003
Operations and maintenance	50.8	63.4	59.7
General and administrative	0	0	0
Loss on long-lived assets, net	(27.3)	(48.2)	(31.4)
Goodwill impairment		(38.8)	(109.1)
Loss on contingent consideration		0
Earnings from unconsolidated affiliates, net	0	0	0
Other income, net		0
EBITDA	47.1	(29.7)	(79.6)
Goodwill	92.7	101.7
Assets	612.5	757.1
Payments to Acquire Property, Plant, and Equipment	5.6	17.7	19.1
Corporate Segment
Segment Reporting Information [Line Items]
Operating revenues	0	0	0
Intersegment Revenues	0	0	0
Costs of product/services sold	0	0	0
Operations and maintenance	0	0	0
General and administrative	88.1	96.5	88.2
Loss on long-lived assets, net	1.7	(3)	0
Goodwill impairment		0	0
Loss on contingent consideration		0
Earnings from unconsolidated affiliates, net	0	0	0
Other income, net	0.4	0.5	0.5
EBITDA	(86)	(99)	(87.7)
Goodwill	0	0
Assets	44.2	13.1
Payments to Acquire Property, Plant, and Equipment	4.6	6.7	1.7
Corporate Segment | CMLP
Segment Reporting Information [Line Items]
Operating revenues	0	0	0
Intersegment Revenues	0	0	0
Costs of product/services sold	0	0	0
Operations and maintenance	0	0	0
General and administrative	83.5	93.1	85.6
Loss on long-lived assets, net	1.7	(3)	0
Goodwill impairment		0	0
Loss on contingent consideration		0
Earnings from unconsolidated affiliates, net	0	0	0
Other income, net		0
EBITDA	(81.8)	(96.1)	(85.6)
Goodwill	0	0
Assets	38	6.6
Payments to Acquire Property, Plant, and Equipment	$ 4.6	$ 6.7	$ 1.7

Segments Disaggregation of Reve

Segments Disaggregation of Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disaggregation of Revenue [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Revenue	$ 343.3	$ 234.1	$ 162.9
Revenues	3,654.1	3,880.9	2,520.5
Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue including intersegment eliminations	1,139.1
Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue including intersegment eliminations	27.6
Revenues	17.1	37.2	165.3
Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenues	2,690.3	$ 2,155.5	$ 1,236.4
Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	134.9
Natural Gas Gathering | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	134.9
Natural Gas Gathering | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Natural Gas Gathering | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	38.8
Crude Oil Gathering | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	38.8
Crude Oil Gathering | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Crude Oil Gathering | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Water Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	58
Water Gathering | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	58
Water Gathering | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Water Gathering | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Natural Gas Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	10.7
Natural Gas Processing | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	10.7
Natural Gas Processing | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Natural Gas Processing | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
NGL Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	6.1
NGL Processing | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
NGL Processing | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
NGL Processing | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	6.1
Natural Gas Compression
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	29.1
Natural Gas Compression | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	29.1
Natural Gas Compression | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Natural Gas Compression | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Crude Oil Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4.5
Crude Oil Storage | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1.8
Crude Oil Storage | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4.2
Crude Oil Storage | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
NGL Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	8.6
NGL Storage | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
NGL Storage | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
NGL Storage | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	8.6
Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4.8
Crude Oil Pipeline | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Crude Oil Pipeline | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	7.1
Crude Oil Pipeline | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	8.8
Crude Oil Transportation | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2.9
Crude Oil Transportation | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Crude Oil Transportation | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	5.9
NGL Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	26.9
NGL Transportation | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
NGL Transportation | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
NGL Transportation | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	26.9
Water Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.3
Water Transportation | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Water Transportation | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Water Transportation | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.3
Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	9.3
Crude Oil Rail Loading | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Crude Oil Rail Loading | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	14.3
Crude Oil Rail Loading | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.2
NGL Rail Loading
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3.1
NGL Rail Loading | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
NGL Rail Loading | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
NGL Rail Loading | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3.1
Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	110.1
Natural Gas Product Sales | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	55.8
Natural Gas Product Sales | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Natural Gas Product Sales | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	70.9
Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,549.6
Crude Oil Product Sales | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	722.9
Crude Oil Product Sales | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Crude Oil Product Sales | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	978
NGL Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,306.7
NGL Product Sales | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	84.2
NGL Product Sales | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
NGL Product Sales | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,247
Other revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0.5
Other revenue | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Other revenue | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2
Other revenue | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenues	(202.9)
Intersegment Eliminations | Natural Gas Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Intersegment Eliminations | Crude Oil Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Intersegment Eliminations | Water Gathering
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Intersegment Eliminations | Natural Gas Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Intersegment Eliminations | NGL Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Intersegment Eliminations | Natural Gas Compression
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Intersegment Eliminations | Crude Oil Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(1.5)
Intersegment Eliminations | NGL Storage
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Intersegment Eliminations | Crude Oil Pipeline
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(2.3)
Intersegment Eliminations | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Intersegment Eliminations | NGL Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Intersegment Eliminations | Water Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Intersegment Eliminations | Crude Oil Rail Loading
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(5.2)
Intersegment Eliminations | NGL Rail Loading
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0
Intersegment Eliminations | Natural Gas Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(16.6)
Intersegment Eliminations | Crude Oil Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(151.3)
Intersegment Eliminations | NGL Product Sales
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(24.5)
Intersegment Eliminations | Other revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(1.5)
Revenue from Contract with Customer
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3,310.8
Revenue from Contract with Customer | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,139.1
Revenue from Contract with Customer | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	27.6
Revenue from Contract with Customer | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,347
Revenue from Contract with Customer | Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(202.9)
Product and Service, Other
Disaggregation of Revenue [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Revenue	343.3
Product and Service, Other | Gathering and Processing Segment
Disaggregation of Revenue [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Revenue	0
Product and Service, Other | Storage and Transportation
Disaggregation of Revenue [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Revenue	0
Product and Service, Other | Marketing Supply and Logistics
Disaggregation of Revenue [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Revenue	343.3
Product and Service, Other | Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Revenue	$ 0

Condensed Consolidating Finan_3

Condensed Consolidating Financial Information (Balance Sheet) (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Current assets:
Cash	$ 0.9	$ 1.3
Restricted cash	16.3	0
Accounts receivable	251.5	442.7
Inventory	64.6	68.4
Total current assets	379.3	530.5
Property, plant and equipment, net	2,029.7	1,820.8
Investments in unconsolidated affiliates	1,188.2	1,183
Other non-current assets	4.9	5.8
Total assets	4,294.5	4,284.9
Current liabilities:
Accounts payable	213	349.4
Total current liabilities	332.1	505.1
Long-term liabilities:
Long-term debt, less current portion	1,752.4	1,491.3
Other long-term liabilities	173.6	104.7
Deferred income taxes	2.6	3.3
Total partners’ capital	2,033.8	2,180.5
Total liabilities and partners’ capital	4,294.5	4,284.9
Eliminations
Current assets:
Cash	0	0
Restricted cash	0
Accounts receivable	(16.3)	0
Inventory	0	0
Other	0	0
Total current assets	(16.3)	0
Property, plant and equipment, net	0	0
Intangible Assets, Net (Including Goodwill)	0	0
Investments in consolidated affiliates	(3,800.4)	(3,705.4)
Investments in unconsolidated affiliates	0	0
Other non-current assets	0	0
Total assets	(3,816.7)	(3,705.4)
Current liabilities:
Accounts payable	(16.3)	0
Total current liabilities	0	0
Total current liabilities	(16.3)	0
Long-term liabilities:
Long-term debt, less current portion	0	0
Other long-term liabilities	0	0
Deferred income taxes	0	0
Partners' capital	(3,800.4)	(3,705.4)
Interest of non-controlling partners in subsidiary	0	0
Total partners’ capital	(3,800.4)	(3,705.4)
Total liabilities and partners’ capital	(3,816.7)	(3,705.4)
Parent Company, Crestwood Midstream Partners, LP | Reportable Legal Entities
Current assets:
Cash	0.2	1
Restricted cash	16.3
Accounts receivable	0	0
Inventory	0	0
Other	0	0
Total current assets	16.5	1
Property, plant and equipment, net	0	0
Intangible Assets, Net (Including Goodwill)	0	0
Investments in consolidated affiliates	3,800.4	3,705.4
Investments in unconsolidated affiliates	0	0
Other non-current assets	0	0
Total assets	3,816.9	3,706.4
Current liabilities:
Accounts payable	16.3	0
Total current liabilities	20	20.5
Total current liabilities	36.3	20.5
Long-term liabilities:
Long-term debt, less current portion	1,752.4	1,490.5
Other long-term liabilities	0	0
Deferred income taxes	0	0
Partners' capital	2,028.2	2,195.4
Interest of non-controlling partners in subsidiary	0	0
Total partners’ capital	2,028.2	2,195.4
Total liabilities and partners’ capital	3,816.9	3,706.4
Guarantor Subsidiaries | Reportable Legal Entities
Current assets:
Cash	0	0
Restricted cash	0
Accounts receivable	246.3	439.7
Inventory	64.6	68.4
Other	46	18.1
Total current assets	356.9	526.2
Property, plant and equipment, net	2,202.3	2,007.5
Intangible Assets, Net (Including Goodwill)	692.4	743.3
Investments in consolidated affiliates	0	0
Investments in unconsolidated affiliates	0	0
Other non-current assets	2.1	2.4
Total assets	3,253.7	3,279.4
Current liabilities:
Accounts payable	210.5	346.8
Total current liabilities	81.8	134
Total current liabilities	292.3	480.8
Long-term liabilities:
Long-term debt, less current portion	0	0.8
Other long-term liabilities	114	45.6
Deferred income taxes	0.6	0.7
Partners' capital	2,846.8	2,751.5
Interest of non-controlling partners in subsidiary	0	0
Total partners’ capital	2,846.8	2,751.5
Total liabilities and partners’ capital	3,253.7	3,279.4
Non-Guarantor Subsidiaries | Reportable Legal Entities
Current assets:
Cash	0	0
Restricted cash	0
Accounts receivable	19.9	2.9
Inventory	0	0
Other	0	0
Total current assets	19.9	2.9
Property, plant and equipment, net	0	0
Intangible Assets, Net (Including Goodwill)	0	0
Investments in consolidated affiliates	0	0
Investments in unconsolidated affiliates	1,188.2	1,183
Other non-current assets	0	0
Total assets	1,208.1	1,185.9
Current liabilities:
Accounts payable	0	0
Total current liabilities	16.2	0
Total current liabilities	16.2	0
Long-term liabilities:
Long-term debt, less current portion	0	0
Other long-term liabilities	57	57
Deferred income taxes	0	0
Partners' capital	953.6	953.9
Interest of non-controlling partners in subsidiary	181.3	175
Total partners’ capital	1,134.9	1,128.9
Total liabilities and partners’ capital	1,208.1	1,185.9
CMLP
Current assets:
Cash	0.2	1
Restricted cash	16.3
Accounts receivable	249.9	442.6
Inventory	64.6	68.4
Other	46	18.1
Total current assets	377	530.1
Property, plant and equipment, net	2,202.3	2,007.5
Intangible Assets, Net (Including Goodwill)	692.4	743.3
Investments in consolidated affiliates	0	0
Investments in unconsolidated affiliates	1,188.2	1,183
Other non-current assets	2.1	2.4
Total assets	4,462	4,466.3
Current liabilities:
Accounts payable	210.5	346.8
Total current liabilities	118	154.5
Total current liabilities	328.5	501.3
Long-term liabilities:
Long-term debt, less current portion	1,752.4	1,491.3
Other long-term liabilities	171	102.6
Deferred income taxes	0.6	0.7
Partners' capital	2,028.2	2,195.4
Interest of non-controlling partners in subsidiary	181.3	175
Total partners’ capital	2,209.5	2,370.4
Total liabilities and partners’ capital	$ 4,462	$ 4,466.3

Condensed Consolidating Finan_4

Condensed Consolidating Financial Information (Statements Of Operations) (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenues:
Revenues		$ 3,654.1	$ 3,880.9	$ 2,520.5
Related party (Note 16)		1	1.8	2.6
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 16)		134.7	15.3	17.7
Total costs of products/services sold		3,129.4	3,374.7	1,925.1
Operating expenses and other:
Operations and maintenance		125.8	136	158.1
General and administrative		88.1	96.5	88.2
Depreciation, amortization and accretion		168.7	191.7	229.6
Loss on long-lived assets, net		28.6	65.6	65.6
Goodwill impairment		0	38.8	162.6
Loss on contingent consideration		0	57	0
Total expenses		411.2	585.6	704.1
Operating income (loss)		113.5	(79.4)	(108.7)
Other income (expense):
Earnings from unconsolidated affiliates, net		53.3	47.8	31.5
Interest and debt expense, net		(99.2)	(99.4)	(125.1)
Gain (loss) on modification/extinguishment of debt	$ 10	(0.9)	(37.7)	10
Other income, net		0.4	1.3	0.5
Loss before income taxes		67.1	(167.4)	(191.8)
(Provision) benefit for income taxes		(0.1)	0.8	(0.3)
Net income (loss)		67	(166.6)	(192.1)
Net income attributable to non-controlling partners in subsidiary		16.2	25.3	24.2
Net income (loss) attributable to parent		50.8	(191.9)	(216.3)
Net income attributable to preferred units		60.1	62.5	28.7
Net income (loss) attributable to partners		(9.3)	(254.4)	(245)
Eliminations
Revenues:
Revenues		0	0	0
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold		0	0	0
Operating expenses and other:
Operations and maintenance		0	0	0
General and administrative		0	0	0
Depreciation, amortization and accretion		0	0	0
Loss on long-lived assets, net		0	0	0
Goodwill impairment			0	0
Loss on contingent consideration			0
Total expenses		0	0	0
Operating income (loss)		0	0	0
Other income (expense):
Earnings from unconsolidated affiliates, net		0	0	0
Interest and debt expense, net		0	0	0
Gain (loss) on modification/extinguishment of debt		0	0	0
Other income, net			0
Loss from unconsolidated affiliates		(197.6)	(3.9)	40.2
Net income (loss)		(197.6)	(3.9)	40.2
Net income attributable to non-controlling partners in subsidiary		0	0	0
Net income (loss) attributable to parent		(197.6)	(3.9)
Net income (loss) attributable to partners				40.2
Parent Company, Crestwood Midstream Partners, LP | Reportable Legal Entities
Revenues:
Revenues		0	0	0
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold		0	0	0
Operating expenses and other:
Operations and maintenance		0	0	0
General and administrative		55.1	67.6	66.4
Depreciation, amortization and accretion		0	0	0
Loss on long-lived assets, net		0	0	0
Goodwill impairment			0	0
Loss on contingent consideration			0
Total expenses		55.1	67.6	66.4
Operating income (loss)		(55.1)	(67.6)	(66.4)
Other income (expense):
Earnings from unconsolidated affiliates, net		0	0	0
Interest and debt expense, net		(99.2)	(99.4)	(125.1)
Gain (loss) on modification/extinguishment of debt		(0.9)	(37.7)	10
Other income, net			0
Loss from unconsolidated affiliates		197.6	3.9	(40.2)
Net income (loss)		42.4	(200.8)	(221.7)
Net income attributable to non-controlling partners in subsidiary		0	0	0
Net income (loss) attributable to parent		42.4	(200.8)
Net income (loss) attributable to partners				(221.7)
Guarantor Subsidiaries | Reportable Legal Entities
Revenues:
Revenues		3,654.1	3,880.9	2,520.5
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold		3,129.4	3,374.7	1,925.1
Operating expenses and other:
Operations and maintenance		125.8	136	155
General and administrative		28.4	25.5	19.2
Depreciation, amortization and accretion		181.4	202.7	240.5
Loss on long-lived assets, net		28.6	65.6	65.6
Goodwill impairment			38.8	162.6
Loss on contingent consideration			0
Total expenses		364.2	468.6	642.9
Operating income (loss)		160.5	37.6	(47.5)
Other income (expense):
Earnings from unconsolidated affiliates, net		0	0	0
Interest and debt expense, net		0	0	0
Gain (loss) on modification/extinguishment of debt		0	0	0
Other income, net			0.8
Loss from unconsolidated affiliates		0	0	0
Net income (loss)		160.5	38.4	(47.5)
Net income attributable to non-controlling partners in subsidiary		0	0	0
Net income (loss) attributable to parent		160.5	38.4
Net income (loss) attributable to partners				(47.5)
Non-Guarantor Subsidiaries | Reportable Legal Entities
Revenues:
Revenues		0	0	0
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold		0	0	0
Operating expenses and other:
Operations and maintenance		0	0	0
General and administrative		0	0	0
Depreciation, amortization and accretion		0	0	0
Loss on long-lived assets, net		0	0	0
Goodwill impairment			0	0
Loss on contingent consideration			57
Total expenses		0	57	0
Operating income (loss)		0	(57)	0
Other income (expense):
Earnings from unconsolidated affiliates, net		53.3	47.8	31.5
Interest and debt expense, net		0	0	0
Gain (loss) on modification/extinguishment of debt		0	0	0
Other income, net			0
Loss from unconsolidated affiliates		0	0	0
Net income (loss)		53.3	(9.2)	31.5
Net income attributable to non-controlling partners in subsidiary		16.2	25.3	24.2
Net income (loss) attributable to parent		37.1	(34.5)
Net income (loss) attributable to partners				7.3
CMLP
Revenues:
Revenues		3,654.1	3,880.9	2,520.5
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold		3,129.4	3,374.7	1,925.1
Operating expenses and other:
Operations and maintenance		125.8	136	155
General and administrative		83.5	93.1	85.6
Depreciation, amortization and accretion		181.4	202.7	240.5
Loss on long-lived assets, net		28.6	65.6	65.6
Goodwill impairment			38.8	162.6
Loss on contingent consideration			57
Total expenses		419.3	593.2	709.3
Operating income (loss)		105.4	(87)	(113.9)
Other income (expense):
Earnings from unconsolidated affiliates, net		53.3	47.8	31.5
Interest and debt expense, net		(99.2)	(99.4)	(125.1)
Gain (loss) on modification/extinguishment of debt		(0.9)	(37.7)	10
Other income, net			0.8
Loss from unconsolidated affiliates		0	0	0
Net income (loss)		58.6	(175.5)	(197.5)
Net income attributable to non-controlling partners in subsidiary		16.2	25.3	24.2
Net income (loss) attributable to parent		$ 42.4	$ (200.8)
Net income (loss) attributable to partners				$ (221.7)

Condensed Consolidating Finan_5

Condensed Consolidating Financial Information (Statements Of Cash Flows) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash flows from operating activities		$ 253.6	$ 255.9	$ 346.1
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired		0	0	(7.2)
Purchases of property, plant and equipment		(305.5)	(188.4)	(100.7)
Investment in unconsolidated affiliates		(64.4)	(58)	(12.4)
Net proceeds from sale of assets		79.5	225.2	972.7
Capital distributions from unconsolidated affiliates		49.2	59.9	14.8
Net cash provided by (used in) investing activities		(241.2)	38.7	867.2
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		2,274.8	2,838.6	1,565.3
Payments on long-term debt		(2,015.7)	(2,913.9)	(2,536.3)
Payments on capital leases		(1.6)	(2.7)	(1.9)
Payments for deferred financing costs		(5.7)	(1)	(3.5)
Redemption of non-controlling interest	$ (202.7)	0	(202.7)	0
Distributions to partners		(170.8)	(167.6)	(219.8)
Net proceeds from issuance of non-controlling interest	(175)	0	(175)	0
Taxes paid for unit-based compensation vesting		(7.4)	(5.5)	(0.8)
Other		(0.1)	(0.1)	0
Net cash provided by (used in) financing activities		3.5	(294.9)	(1,212.2)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect		15.9	(0.3)	1.1
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	1.3	17.2	1.3	1.6	$ 0.5
Eliminations
Cash flows from operating activities		0	0	0
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired				0
Purchases of property, plant and equipment		0	0	0
Investment in unconsolidated affiliates		0	0	0
Net proceeds from sale of assets		0	0	0
Capital distributions from unconsolidated affiliates		0	0	0
Contributions to (Distributions from) Consolidated Affiliates		(27.9)	(4.3)	(26.2)
Net cash provided by (used in) investing activities		(27.9)	(4.3)	(26.2)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		0	0	0
Payments on long-term debt		0	0	0
Payments on capital leases		0	0	0
Payments for deferred financing costs		0	0	0
Financing fees paid for early debt redemption			0
Distributions to partners		0	0	0
Contributions from (Distributions to) Parent		27.9	4.3	26.2
Net proceeds from issuance of non-controlling interest			0
Taxes paid for unit-based compensation vesting		0	0	0
Change in intercompany balances		0	0	0
Other		0	0
Net cash provided by (used in) financing activities		27.9	4.3	26.2
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect		0	0	0
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	0	0	0	0	0
Parent Company, Crestwood Midstream Partners, LP | Reportable Legal Entities
Cash flows from operating activities		(131.7)	(162.3)	(188)
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired				0
Purchases of property, plant and equipment		0	0	0
Investment in unconsolidated affiliates		0	0	0
Net proceeds from sale of assets		0	0	0
Capital distributions from unconsolidated affiliates		0	0	0
Contributions to (Distributions from) Consolidated Affiliates		27.9	4.3	26.2
Net cash provided by (used in) investing activities		27.9	4.3	26.2
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		2,274.8	2,838.6	1,565.3
Payments on long-term debt		(2,014.8)	(2,912.6)	(2,535.3)
Payments on capital leases		0	0	0
Payments for deferred financing costs		(5.7)	(1)	(3.5)
Financing fees paid for early debt redemption			0
Distributions to partners		(238.4)	(174)	(227.6)
Contributions from (Distributions to) Parent		0	0	0
Net proceeds from issuance of non-controlling interest			0
Taxes paid for unit-based compensation vesting		0	0	0
Change in intercompany balances		103.4	406.7	1,364.1
Other		0	0
Net cash provided by (used in) financing activities		119.3	157.7	163
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect		15.5	(0.3)	1.2
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	1	16.5	1	1.3	0.1
CMLP
Cash flows from operating activities		260.5	262.2	353.8
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired				(7.2)
Purchases of property, plant and equipment		(305.5)	(188.4)	(100.7)
Investment in unconsolidated affiliates		(64.4)	(58)	(12.4)
Net proceeds from sale of assets		79.5	225.2	972.7
Capital distributions from unconsolidated affiliates		49.2	59.9	14.8
Contributions to (Distributions from) Consolidated Affiliates		0	0	0
Net cash provided by (used in) investing activities		(241.2)	38.7	867.2
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		2,274.8	2,838.6	1,565.3
Payments on long-term debt		(2,015.7)	(2,913.9)	(2,536.1)
Payments on capital leases		(1.6)	(2.7)	(1.9)
Payments for deferred financing costs		(5.7)	(1)	(3.5)
Financing fees paid for early debt redemption			(202.7)
Distributions to partners		(248.3)	(189.2)	(242.8)
Contributions from (Distributions to) Parent		0	0	0
Net proceeds from issuance of non-controlling interest			(175)
Taxes paid for unit-based compensation vesting		(7.4)	(5.5)	(0.8)
Change in intercompany balances		0	0	0
Other		0.1	0.2
Net cash provided by (used in) financing activities		(3.8)	(301.2)	(1,219.8)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect		15.5	(0.3)	1.2
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	1	16.5	1	1.3	0.1
Non-Guarantor Subsidiaries | Reportable Legal Entities
Cash flows from operating activities		53	45.3	39
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired				0
Purchases of property, plant and equipment		0	0	0
Investment in unconsolidated affiliates		(64.4)	(58)	(12.4)
Net proceeds from sale of assets		0	0	0
Capital distributions from unconsolidated affiliates		49.2	59.9	14.8
Contributions to (Distributions from) Consolidated Affiliates		0	0	0
Net cash provided by (used in) investing activities		(15.2)	1.9	2.4
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		0	0	0
Payments on long-term debt		0	0	0
Payments on capital leases		0	0	0
Payments for deferred financing costs		0	0	0
Financing fees paid for early debt redemption			(202.7)
Distributions to partners		(9.9)	(15.2)	(15.2)
Contributions from (Distributions to) Parent		(27.9)	(4.3)	(26.2)
Net proceeds from issuance of non-controlling interest			(175)
Taxes paid for unit-based compensation vesting		0	0	0
Change in intercompany balances		0	0	0
Other		0	0
Net cash provided by (used in) financing activities		(37.8)	(47.2)	(41.4)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect		0	0	0
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	0	0	0	0	0
Guarantor Subsidiaries | Reportable Legal Entities
Cash flows from operating activities		339.2	379.2	502.8
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired				(7.2)
Purchases of property, plant and equipment		(305.5)	(188.4)	(100.7)
Investment in unconsolidated affiliates		0	0	0
Net proceeds from sale of assets		79.5	225.2	972.7
Capital distributions from unconsolidated affiliates		0	0	0
Contributions to (Distributions from) Consolidated Affiliates		0	0	0
Net cash provided by (used in) investing activities		(226)	36.8	864.8
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		0	0	0
Payments on long-term debt		(0.9)	(1.3)	(0.8)
Payments on capital leases		(1.6)	(2.7)	(1.9)
Payments for deferred financing costs		0	0	0
Financing fees paid for early debt redemption			0
Distributions to partners		0	0	0
Contributions from (Distributions to) Parent		0	0	0
Net proceeds from issuance of non-controlling interest			0
Taxes paid for unit-based compensation vesting		(7.4)	(5.5)	(0.8)
Change in intercompany balances		(103.4)	(406.7)	(1,364.1)
Other		0.1	0.2
Net cash provided by (used in) financing activities		(113.2)	(416)	(1,367.6)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect		0	0	0
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	0	0	0	0	0
CMLP
Cash flows from operating activities		260.5	262.2	353.8
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired		0	0	(7.2)
Purchases of property, plant and equipment		(305.5)	(188.4)	(100.7)
Investment in unconsolidated affiliates		(64.4)	(58)	(12.4)
Net proceeds from sale of assets		79.5	225.2	972.7
Capital distributions from unconsolidated affiliates		49.2	59.9	14.8
Net cash provided by (used in) investing activities		(241.2)	38.7	867.2
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		2,274.8	2,838.6	1,565.3
Payments on long-term debt		(2,015.7)	(2,913.9)	(2,536.1)
Payments on capital leases		(1.6)	(2.7)	(1.9)
Payments for deferred financing costs		(5.7)	(1)	(3.5)
Redemption of non-controlling interest		0	(202.7)	0
Distributions to partners		(238.4)	(174)	(227.6)
Net proceeds from issuance of non-controlling interest		0	(175)	0
Taxes paid for unit-based compensation vesting		(7.4)	(5.5)	(0.8)
Other		0.1	0.2	0
Net cash provided by (used in) financing activities		(3.8)	(301.2)	(1,219.8)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect		15.5	(0.3)	1.2
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	$ 1	$ 16.5	$ 1	$ 1.3	$ 0.1

Schedule I - Crestwood Equity_2

Schedule I - Crestwood Equity Partners LP - Parent Only - Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Cash	$ 0.9	$ 1.3
Total current assets	379.3	530.5
Property, plant and equipment, net	2,029.7	1,820.8
Total assets	4,294.5	4,284.9
Accrued expenses	112.4	105.9
Total current liabilities	332.1	505.1
Other long-term liabilities	173.6	104.7
Total partners’ capital	2,033.8	2,180.5
Total liabilities and partners’ capital	4,294.5	4,284.9
Parent Company
Condensed Financial Statements, Captions [Line Items]
Cash	0.2	0.3	$ 0.3	$ 0.4
Total current assets	0.2	0.3
Property, plant and equipment, net	1.1	1.2
Intangible assets, net	0	1.4
Investments in subsidiaries	1,854.7	2,005.1
Other assets	2.8	3.5
Total assets	1,858.8	2,011.5
Accounts payable	2.6	2.7
Accrued expenses	1.1	1.2
Total current liabilities	3.7	3.9
Other long-term liabilities	2.6	2.1
Total partners’ capital	1,852.5	2,005.5
Total liabilities and partners’ capital	$ 1,858.8	$ 2,011.5

Schedule I - Crestwood Equity_3

Schedule I - Crestwood Equity Partners LP - Parent Only - Statement of Operations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Condensed Financial Statements, Captions [Line Items]
Revenues	$ 3,654.1	$ 3,880.9	$ 2,520.5
Operating income (loss)	113.5	(79.4)	(108.7)
Other income, net	0.4	1.3	0.5
Net income (loss)	67	(166.6)	(192.1)
Net income attributable to non-controlling partners in subsidiary	16.2	25.3	24.2
Net income (loss) attributable to parent	50.8	(191.9)	(216.3)
Parent Company
Condensed Financial Statements, Captions [Line Items]
Revenues	0	0	0
Costs and Expenses	6.1	6.7	6
Operating income (loss)	(6.1)	(6.7)	(6)
Loss from unconsolidated affiliates	72.7	(160.4)	(186.6)
Other income, net	0.4	0.5	0.5
Net income (loss)	67	(166.6)	(192.1)
Net income attributable to non-controlling partners in subsidiary	16.2	25.3	24.2
Net income (loss) attributable to parent	$ 50.8	$ (191.9)	$ (216.3)

Schedule I - Crestwood Equity_4

Schedule I - Crestwood Equity Partners LP - Parent Only - Statement of Comprehensive Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	$ 67	$ (166.6)	$ (192.1)
Change in fair value of Suburban Propane Partners, LP units	(0.7)	(0.8)	0.8
Comprehensive income (loss)	66.3	(167.4)	(191.3)
Comprehensive income (loss) attributable to non-controlling partners	(16.2)	(25.3)	(24.2)
Comprehensive income (loss) attributable to Crestwood Equity Partners LP	50.1	(192.7)	(215.5)
Parent Company
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	67	(166.6)	(192.1)
Change in fair value of Suburban Propane Partners, LP units	(0.7)	(0.8)	0.8
Comprehensive income (loss)	66.3	(167.4)	(191.3)
Comprehensive income (loss) attributable to non-controlling partners	(16.2)	(25.3)	(24.2)
Comprehensive income (loss) attributable to Crestwood Equity Partners LP	$ 50.1	$ (192.7)	$ (215.5)

Schedule I - Crestwood Equity_5

Schedule I - Crestwood Equity Partners LP - Parent Only - Condensed Statement of Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	$ 253.6	$ 255.9	$ 346.1
Cash flows from investing activities	(241.2)	38.7	867.2
Payments on long-term debt	(2,015.7)	(2,913.9)	(2,536.3)
Distributions to partners	(170.8)	(167.6)	(219.8)
Net proceeds from issuance of common units	0	15.2	0
Net cash provided by (used in) financing activities	3.5	(294.9)	(1,212.2)
Cash at beginning of period	1.3
Cash at end of period	0.9	1.3
Parent Company
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	(3.8)	(3.6)	(3.5)
Dividends received from CMLP	238.4	174	227.6
Cash flows from investing activities		174	227.6
Payments on long-term debt	0	0	(0.2)
Distributions to partners	(230.9)	(182.6)	(219.8)
Net proceeds from issuance of common units	0	15.2	0
Change in intercompany balances	(3.8)	(3)	(4.2)
Net cash provided by (used in) financing activities	(234.7)	(170.4)	(224.2)
Net change in cash	(0.1)	0	(0.1)
Cash at beginning of period	0.3	0.3	0.4
Cash at end of period	$ 0.2	$ 0.3	$ 0.3

Schedule I - Crestwood Equity_6

Schedule I - Crestwood Equity Partners LP - Parent Only - Distributions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Parent Company
Dividends received from CMLP	$ 238.4	$ 174	$ 227.6

Schedule II - Crestwood Equit_2

Schedule II - Crestwood Equity Partners LP - Valuation and Qualifying Accounts (Details) - Allowance for Doubtful Accounts - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount	$ 2.4	$ 1.9	$ 0.4
Valuation Allowances and Reserves, Charged to Cost and Expense	0.2	1.5	1.9
Valuation Allowances and Reserves, Charged to Other Accounts	0	0	0
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction	(2.3)	(1)	(0.4)
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount	$ 0.3	$ 2.4	$ 1.9