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Document and Entity Information - USD ($) $ in Billions	12 Months Ended
Document and Entity Information - USD ($) $ in Billions	Dec. 31, 2017	Feb. 12, 2018	Jun. 30, 2017
Entity Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	FY
Trading Symbol	CEQP
Entity Registrant Name	Crestwood Equity Partners LP
Entity Central Index Key	0001136352
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		71,231,599
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 1.1
CMLP
Entity Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	FY
Entity Registrant Name	Crestwood Midstream Partners LP
Entity Central Index Key	0001304464
Current Fiscal Year End Date	--12-31
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			$ 0.0

Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Assets
Cash	$ 1.3	$ 1.6
Accounts receivable, less allowance for doubtful accounts	442.7	289.8
Inventory	68.4	66.0
Assets from price risk management activities	7.2	6.3
Prepaid expenses and other current assets	10.9	9.7
Total current assets	530.5	373.4
Property, plant and equipment	2,285.2	2,555.4
Less: accumulated depreciation and depletion	464.4	457.8
Property, plant and equipment, net	1,820.8	2,097.6
Intangible assets	788.8	898.6
Less: accumulated amortization	191.6	241.2
Intangible assets, net	597.2	657.4
Goodwill	147.6	199.0
Investments in unconsolidated affiliates	1,183.0	1,115.4
Other assets	5.8	6.1
Total assets	4,284.9	4,448.9
Current liabilities:
Accounts payable	349.4	217.2
Accrued expenses and other liabilities	105.9	90.5
Liabilities from price risk management activities	48.9	28.6
Current portion of long-term debt	0.9	1.0
Total current liabilities	505.1	337.3
Long-term debt, less current portion	1,491.3	1,522.7
Other long-term liabilities	104.7	44.6
Deferred income taxes	3.3	5.3
Commitments and contingencies (Note 15)
Partners’ capital:
Partners' capital	1,393.5	1,782.0
Preferred units	612.0	564.5
Total CEQP/CMLP partners’ capital	2,005.5	2,346.5
Interest of non-controlling partners in subsidiaries	175.0	192.5
Total partners’ capital	2,180.5	2,539.0
Total liabilities and partners’ capital	4,284.9	4,448.9
CMLP
Assets
Cash	1.0	1.3
Accounts receivable, less allowance for doubtful accounts	442.6	289.8
Inventory	68.4	66.0
Assets from price risk management activities	7.2	6.3
Prepaid expenses and other current assets	10.9	9.7
Total current assets	530.1	373.1
Property, plant and equipment	2,615.3	2,885.5
Less: accumulated depreciation and depletion	607.8	587.1
Property, plant and equipment, net	2,007.5	2,298.4
Intangible assets	773.3	883.1
Less: accumulated amortization	177.6	230.2
Intangible assets, net	595.7	652.9
Goodwill	147.6	199.0
Investments in unconsolidated affiliates	1,183.0	1,115.4
Other assets	2.4	1.8
Total assets	4,466.3	4,640.6
Current liabilities:
Accounts payable	346.8	214.5
Accrued expenses and other liabilities	104.7	87.9
Liabilities from price risk management activities	48.9	28.6
Current portion of long-term debt	0.9	1.0
Total current liabilities	501.3	332.0
Long-term debt, less current portion	1,491.3	1,522.7
Other long-term liabilities	102.6	42.0
Deferred income taxes	0.7	0.7
Partners’ capital:
Total CEQP/CMLP partners’ capital	2,195.4	2,550.7
Interest of non-controlling partners in subsidiaries	175.0	192.5
Total partners’ capital	2,370.4	2,743.2
Total liabilities and partners’ capital	$ 4,466.3	$ 4,640.6

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Allowance for doubtful accounts	$ 2.4	$ 1.9
Limited partners' units, issued	70,721,563	69,499,741
Limited partners' units, outstanding	70,721,563	69,499,741
Preferred units, issued	71,257,445	66,533,415
Preferred units, outstanding	71,257,445	66,533,415
CMLP
Allowance for doubtful accounts	$ 2.4	$ 1.9

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenues:
Gathering and processing	$ 1,369.1	$ 825.5	$ 1,051.2
Marketing, supply and logistics	2,093.1	1,144.3	857.5
Total product revenue	3,462.2	1,969.8	1,908.7
Gathering and processing	317.3	290.7	325.9
Storage and transportation	37.2	165.3	266.3
Marketing, supply and logistics	62.4	92.1	128.0
Related party (Note 16)	1.8	2.6	3.9
Total services revenues	418.7	550.7	724.1
Total revenues	3,880.9	2,520.5	2,632.8
Costs of product/services sold (exclusive of items shown separately below):
Product costs	3,309.5	1,851.9	1,780.0
Product costs - related party (Note 16)	15.3	17.7	28.9
Service costs	49.9	55.5	74.6
Total costs of products/services sold	3,374.7	1,925.1	1,883.5
Expenses:
Operations and maintenance	136.0	158.1	190.2
General and administrative	96.5	88.2	116.3
Depreciation, amortization and accretion	191.7	229.6	300.1
Total expenses	424.2	475.9	606.6
Loss on long-lived assets, net	(65.6)	(65.6)	(821.2)
Goodwill impairment	(38.8)	(162.6)	(1,406.3)
Loss on contingent consideration	(57.0)	0.0	0.0
Operating income (loss)	(79.4)	(108.7)	(2,084.8)
Earnings (loss) from unconsolidated affiliates, net	47.8	31.5	(60.8)
Interest and debt expense, net	(99.4)	(125.1)	(140.1)
Gain (loss) on modification/extinguishment of debt	(37.7)	10.0	(20.0)
Other income, net	1.3	0.5	0.6
Loss before income taxes	(167.4)	(191.8)	(2,305.1)
(Provision) benefit for income taxes	0.8	(0.3)	1.4
Net loss	(166.6)	(192.1)	(2,303.7)
Net income (loss) attributable to non-controlling partners	(25.3)	(24.2)	636.8
Net income (loss) attributable to parent	(191.9)	(216.3)	(1,666.9)
Net income attributable to preferred units	62.5	28.7	6.2
Net loss attributable to partners	(254.4)	(245.0)	(1,673.1)
Common unitholders’ interest in net loss	$ (254.4)	$ (245.0)	$ (1,673.1)
Net loss per limited partner unit:
Basic (dollars per unit)	$ (3.64)	$ (3.55)	$ (54.00)
Diluted (dollars per unit)	$ (3.64)	$ (3.55)	$ (54.00)
Weighted-average limited partners’ units outstanding (in thousands):
Basic (units)	69,839	69,017	30,983
Dilutive units (units)	0	0	0
Diluted (units)	69,839	69,017	30,983
CMLP
Revenues:
Gathering and processing	$ 1,369.1	$ 825.5	$ 1,051.2
Marketing, supply and logistics	2,093.1	1,144.3	857.5
Total product revenue	3,462.2	1,969.8	1,908.7
Gathering and processing	317.3	290.7	325.9
Storage and transportation	37.2	165.3	266.3
Marketing, supply and logistics	62.4	92.1	128.0
Related party (Note 16)	1.8	2.6	3.9
Total services revenues	418.7	550.7	724.1
Total revenues	3,880.9	2,520.5	2,632.8
Costs of product/services sold (exclusive of items shown separately below):
Product costs	3,309.5	1,851.9	1,780.0
Product costs - related party (Note 16)	15.3	17.7	28.9
Service costs	49.9	55.5	74.6
Total costs of products/services sold	3,374.7	1,925.1	1,883.5
Expenses:
Operations and maintenance	136.0	155.0	188.7
General and administrative	93.1	85.6	105.6
Depreciation, amortization and accretion	202.7	240.5	278.5
Total expenses	431.8	481.1	572.8
Loss on long-lived assets, net	(65.6)	(65.6)	(227.8)
Goodwill impairment	(38.8)	(162.6)	(1,149.1)
Loss on contingent consideration	(57.0)	0.0	0.0
Operating income (loss)	(87.0)	(113.9)	(1,200.4)
Earnings (loss) from unconsolidated affiliates, net	47.8	31.5	(60.8)
Interest and debt expense, net	(99.4)	(125.1)	(130.5)
Gain (loss) on modification/extinguishment of debt	(37.7)	10.0	(18.9)
Other income, net	0.8	0.0	0.0
(Provision) benefit for income taxes	0.0	0.0	0.0
Net loss	(175.5)	(197.5)	(1,410.6)
Net income (loss) attributable to non-controlling partners	(25.3)	(24.2)	(23.1)
Net income (loss) attributable to parent	(200.8)	(221.7)	(1,433.7)
Net income attributable to preferred units	0.0	0.0	23.1
Net loss attributable to partners	$ (200.8)	$ (221.7)	$ (1,456.8)

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Statement of Comprehensive Income [Abstract]
Net loss	$ (166.6)	$ (192.1)	$ (2,303.7)
Change in fair value of Suburban Propane Partners, L.P. units	(0.8)	0.8	(2.7)
Comprehensive loss	(167.4)	(191.3)	(2,306.4)
Comprehensive income (loss) attributable to non-controlling partners	(25.3)	(24.2)	636.8
Comprehensive loss attributable to Crestwood Equity Partners LP	$ (192.7)	$ (215.5)	$ (1,669.6)

Consolidated Statement of Partners' Capital - USD ($) $ in Millions	Total	CMLP	Common Unit Capital	Common Unit Capital CMLP	Preferred Units	Preferred Units CMLP	Limited Partners	Limited Partners CMLP	Non-Controlling Partners	Non-Controlling Partners CMLP	Partners' Capital [Member]	Preferred Units, Class A	Preferred Units, Class A Preferred Units	Preferred Units, Class A Limited Partners	Preferred Units, Class A Non-Controlling Partners	Subordinated units	Common units	Preferred Units
Common Unit, Outstanding																400,000	18,200,000
Preferred units, outstanding																		0
Partners' Capital Account, Units, Acquisitions																	49,900,000	59,300,000
Balance at the beginning of the period at Dec. 31, 2014	$ 5,584.5	$ 5,320.4			$ 0.0	$ 447.7	$ 776.2	$ 4,701.0	$ 4,808.3	$ 171.7
Increase (Decrease) in Partners' Capital [Roll Forward]
Unit-based compensation charges	19.7	18.1			0.0	0.0	5.7	18.1	14.0	0.0
Partners' Capital Account, Units, Unit-based Compensation																	100,000
Taxes paid for unit-based compensation vesting	(3.7)	(2.1)			0.0	0.0	(1.6)	(2.1)	(2.1)	0.0
Distributions to partners	(405.7)	(819.5)			0.0	0.0	(171.5)	(808.2)	(234.2)	(11.3)
Issuance of CMLP Class A preferred units		58.8				58.8		0.0		0.0
Partners' Capital Account, Exchanges and Conversions	0.0	0.0			529.6	(529.6)	3,294.8	529.6	(3,824.4)	0.0
Issuance of preferred equity of subsidiary												$ 58.8	$ 0.0	$ 0.0	$ 58.8
Change in fair value of Suburban Propane Partners, LP units	(2.7)				0.0		(2.7)		0.0
Other	(0.3)				0.0		(0.2)		(0.1)
Net loss	(2,303.7)	(1,410.6)			6.2	23.1	(1,673.1)	(1,456.8)	(636.8)	23.1
Balance at the end of the period at Dec. 31, 2015	2,946.9	3,165.1			535.8	0.0	2,227.6	2,981.6	183.5	183.5
Common Unit, Outstanding																400,000	68,200,000
Preferred units, outstanding																		60,700,000
Increase (Decrease) in Partners' Capital [Roll Forward]
Preferred units, issued													1,400,000
Unit-based compensation charges	19.2	19.2			0.0	0.0	19.2	19.2	0.0	0.0
Partners' Capital Account, Units, Unit-based Compensation																	900,000
Taxes paid for unit-based compensation vesting	(0.8)	(0.8)			0.0	0.0	(0.8)	(0.8)	0.0	0.0
Distributions to partners	(235.0)	(242.8)			0.0	0.0	(219.8)	(227.6)	(15.2)	(15.2)
Issuance of CMLP Class A preferred units		0.0
Preferred Stock Dividends, Shares																		5,800,000
Change in fair value of Suburban Propane Partners, LP units	0.8				0.0		0.8		0.0
Net loss	(192.1)	(197.5)			28.7	0.0	(245.0)	(221.7)	24.2	24.2
Balance at the end of the period at Dec. 31, 2016	$ 2,539.0	2,743.2			564.5	0.0	1,782.0	2,550.7	192.5	192.5
Common Unit, Outstanding																400,000	69,100,000
Preferred units, outstanding	66,533,415																	66,500,000
Increase (Decrease) in Partners' Capital [Roll Forward]
Preferred units, issued	66,533,415
Proceeds from the issuance of common units			$ 15.2		0.0				0.0		$ 15.2
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	$ 0.0	(202.7)	0.0		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	25.5			0.0	0.0	25.5	25.5	0.0	0.0
Partners' Capital Account, Units, Unit-based Compensation																	800,000
Taxes paid for unit-based compensation vesting	(5.5)	(5.5)			0.0	0.0	(5.5)	(5.5)	0.0	0.0
Shares Paid for Tax Withholding for Share Based Compensation																	(200,000)
Distributions to partners	(197.8)	(189.2)			(15.0)	0.0	(167.6)	(174.0)	(15.2)	(15.2)
Issuance of CMLP Class A preferred units		0.0
Issuance of preferred equity of subsidiary	0.0	175.0	0.0		0.0				175.0	175.0	175.0
Preferred Stock Dividends, Shares																		4,800,000
Change in fair value of Suburban Propane Partners, LP units	(0.8)				0.0		(0.8)		0.0
Other		(0.4)	$ (0.9)	$ (0.5)	0.0	0.0			0.1	0.1	$ (0.8)
Net loss	(166.6)	(175.5)			62.5	0.0	(254.4)	(200.8)	25.3	25.3
Balance at the end of the period at Dec. 31, 2017	$ 2,180.5	$ 2,370.4			$ 612.0	$ 0.0	$ 1,393.5	$ 2,195.4	$ 175.0	$ 175.0
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

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating activities
Net loss	$ (166.6)	$ (192.1)	$ (2,303.7)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, amortization and accretion	191.7	229.6	300.1
Amortization of debt-related deferred costs	7.2	6.9	8.9
Market adjustment on interest rate swaps	0.0	0.0	(0.5)
Unit-based compensation charges	25.5	19.2	19.7
Loss on long-lived assets, net	(65.6)	(65.6)	(821.2)
Goodwill impairment	38.8	162.6	1,406.3
Loss on contingent consideration	57.0	0.0	0.0
(Gain) loss on modification/extinguishment of debt	37.7	(10.0)	20.0
(Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received	(0.1)	7.6	73.6
Deferred income taxes	(2.1)	(3.1)	(3.6)
Other	0.9	1.9	0.7
Changes in operating assets and liabilities:
Accounts receivable	(170.7)	(76.9)	119.7
Inventory	(9.9)	(22.5)	2.0
Prepaid expenses and other current assets	1.8	9.2	1.8
Accounts payable, accrued expenses and other liabilities	140.1	74.6	(128.0)
Reimbursements of property, plant and equipment	19.6	26.0	73.3
Change in price risk management activities, net	19.4	47.5	29.2
Net cash provided by operating activities	255.9	346.1	440.7
Investing activities
Acquisitions, net of cash acquired	0.0	(7.2)	0.0
Purchases of property, plant and equipment	(188.4)	(100.7)	(182.7)
Investment in unconsolidated affiliates	(58.0)	(12.4)	(42.0)
Capital distributions from unconsolidated affiliates	59.9	14.8	9.3
Net proceeds from sale of assets	225.2	972.7	2.7
Net cash provided by (used in) investing activities	38.7	867.2	(212.7)
Financing activities
Proceeds from the issuance of long-term debt	2,838.6	1,565.3	4,261.8
Payments on long-term debt	(2,913.9)	(2,536.3)	(4,113.0)
Payments on capital leases	(2.7)	(1.9)	(2.2)
Payments for debt-related deferred costs	(1.0)	(3.5)	(17.3)
Financing fees paid for early debt redemption	0.0	0.0	(13.6)
Payments for Repurchase of Redeemable Noncontrolling Interest	(202.7)	0.0	0.0
Distributions to partners	(167.6)	(219.8)	(171.5)
Distributions paid to non-controlling partners	(15.2)	(15.2)	(234.2)
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	15.0	0.0	0.0
Net proceeds from issuance of preferred equity of subsidiary	(175.0)	0.0	0.0
Taxes paid for unit-based compensation vesting	(5.5)	(0.8)	(3.8)
Net proceeds from issuance of common units	15.2	0.0	0.0
Other	(0.1)	0.0	(1.3)
Net cash used in financing activities	(294.9)	(1,212.2)	(236.3)
Net change in cash	(0.3)	1.1	(8.3)
Cash at beginning of period	1.6	0.5	8.8
Cash at end of period	1.3	1.6	0.5
Supplemental disclosure of cash flow information
Cash paid during the period for interest	95.1	121.5	129.0
Cash paid during the period for income taxes	3.1	1.4	4.7
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	(20.4)	(10.5)	(14.1)
Preferred Units, Class A
Financing activities
Net proceeds from issuance of preferred equity of subsidiary	0.0	0.0	(58.8)
CMLP
Operating activities
Net loss	(175.5)	(197.5)	(1,410.6)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, amortization and accretion	202.7	240.5	278.5
Amortization of debt-related deferred costs	7.2	6.9	8.1
Unit-based compensation charges	25.5	19.2	18.1
Loss on long-lived assets, net	(65.6)	(65.6)	(227.8)
Goodwill impairment	38.8	162.6	1,149.1
Loss on contingent consideration	57.0	0.0	0.0
(Gain) loss on modification/extinguishment of debt	37.7	(10.0)	18.9
(Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received	(0.1)	7.6	73.6
Deferred income taxes	0.0	0.2	(0.3)
Other	0.9	1.9	0.7
Changes in operating assets and liabilities:
Accounts receivable	(170.5)	(76.9)	119.4
Inventory	(9.9)	(22.5)	2.1
Prepaid expenses and other current assets	1.8	7.5	3.7
Accounts payable, accrued expenses and other liabilities	142.0	75.2	(119.8)
Reimbursements of property, plant and equipment	19.6	26.0	73.3
Change in price risk management activities, net	19.4	47.5	29.2
Net cash provided by operating activities	262.2	353.8	471.8
Investing activities
Acquisitions, net of cash acquired	0.0	(7.2)	0.0
Purchases of property, plant and equipment	(188.4)	(100.7)	(182.7)
Investment in unconsolidated affiliates	(58.0)	(12.4)	(41.8)
Capital distributions from unconsolidated affiliates	59.9	14.8	9.3
Net proceeds from sale of assets	225.2	972.7	2.7
Net cash provided by (used in) investing activities	38.7	867.2	(212.5)
Financing activities
Proceeds from the issuance of long-term debt	2,838.6	1,565.3	3,490.1
Payments on long-term debt	(2,913.9)	(2,536.1)	(2,960.9)
Payments on capital leases	(2.7)	(1.9)	(2.2)
Payments for debt-related deferred costs	(1.0)	(3.5)	(17.3)
Financing fees paid for early debt redemption	0.0	0.0	(13.6)
Payments for Repurchase of Redeemable Noncontrolling Interest	(202.7)	0.0
Distributions to partners	(189.2)	(242.8)	(819.5)
Net proceeds from issuance of preferred equity of subsidiary	(175.0)	0.0	0.0
Issuance of CMLP Class A preferred units	0.0	0.0	58.8
Taxes paid for unit-based compensation vesting	(5.5)	(0.8)	(2.1)
Other	0.2	0.0	(0.1)
Net cash used in financing activities	(301.2)	(1,219.8)	(266.8)
Net change in cash	(0.3)	1.2	(7.5)
Cash at beginning of period	1.3	0.1	7.6
Cash at end of period	1.0	1.3	0.1
Supplemental disclosure of cash flow information
Cash paid during the period for interest	95.1	121.5	118.2
Cash paid during the period for income taxes	0.6	0.7	0.6
Supplemental schedule of noncash investing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$ (20.4)	$ (10.5)	$ (14.1)

Organization and Description of Business

12 Months Ended

Dec. 31, 2017

Disclosure Partnership Organization And Basis Of Presentation Narrative [Abstract]

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, 2017:

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, Nevada, New Jersey, New York, Rhode Island and Wyoming, our truck terminal located in Utah, and our truck maintenance facilities located in Indiana, Mississippi, New Jersey and Ohio; (ii) our West Coast processing and fractionation operations located in California; (iii) our Bath and Seymour NGL storage facilities located in New York and Indiana; and (iv) our crude oil and produced water transportation assets.

Basis of Presentation and Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2017

Accounting Policies [Abstract]

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.

In September 2015, Crestwood Midstream merged with a wholly-owned subsidiary of CEQP, with Crestwood Midstream surviving as a wholly-owned subsidiary of CEQP (the Simplification Merger), and CEQP contributed 100% of its interest in Crestwood Operations LLC (Crestwood Operations) to Crestwood Midstream. As a result of this transaction, Crestwood Midstream controls the operating and financial decisions of Crestwood Operations. Crestwood Midstream accounted for this transaction as a reorganization of entities under common control and the accounting standards related to such transactions requires Crestwood Midstream to record the assets and liabilities of Crestwood Operations at CEQP’s carrying value and retroactively adjust Crestwood Midstream’s historical results to reflect the operations of Crestwood Operations as being acquired on June 19, 2013, the date in which Crestwood Midstream and Crestwood Operations came under common control. Prior to the Simplification Merger, Crestwood Equity consolidated the results of Crestwood Operations in its financial statements and as such, this transaction had no impact on its historical financial statements.

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 a joint venture, Crestwood Permian, 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 (which is currently estimated to cost approximately $180 million) 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, 2017 and 2016. See Note 6 for a further discussion of our investment in Crestwood Permian.

On June 21, 2017, we contributed to Crestwood Permian 100% of the equity interest of Crestwood New Mexico Pipeline LLC (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 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. Crestwood New Mexico was previously included in our G&P segment. The deconsolidation of Crestwood New Mexico was not material to our consolidated financial statements as of and for the year ended December 31, 2017.

On June 3, 2016, our wholly-owned subsidiary, Crestwood Pipeline and Storage Northeast LLC (Crestwood Northeast) and Con Edison Gas Pipeline and Storage Northeast, LLC (CEGP), a wholly-owned subsidiary of Consolidated Edison, Inc. (Consolidated Edison), formed the Stagecoach Gas Services LLC (Stagecoach Gas) joint venture, to own and further develop our natural gas storage and transportation business located in the Northeast (the NE S&T assets). We contributed to the joint venture the entities owning the NE S&T assets, CEGP contributed $975 million in exchange for a 50% equity interest in Stagecoach Gas, and Stagecoach Gas distributed to us the net cash proceeds received from CEGP. The assets contributed to the joint venture were previously included in our S&T segment.

We deconsolidated the NE S&T assets as a result of the contribution of these assets to Stagecoach Gas and began accounting for our 50% equity interest in Stagecoach Gas under the equity method of accounting. The deconsolidation of our NE S&T assets resulted in a decrease of $1,127.6 million in property, plant and equipment, net, $8.5 million of intangible assets, net and $11.2 million of other assets and (liabilities), net. For a discussion of the decrease in goodwill associated with this joint venture transaction, see “Goodwill” below. See Note 6 for a further discussion of our investment in Stagecoach Gas.

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.

Inventory

Inventory for our marketing, supply and logistics operations are stated at the lower of cost or market and cost is computed predominantly using the average cost method. Our inventory consists primarily of crude oil and NGLs of approximately $67.9 million and $56.7 million at December 31, 2017 and 2016.

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.

During 2017 and 2015, we recorded the following impairments of our property, plant and equipment and we reflected these impairments in loss on long-lived assets in our consolidated statements of operations. We did not record impairments of our property, plant and equipment during the year ended December 31, 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. The fair value of our property, plant and equipment related to our West Coast operation was $66.4 million as of December 31, 2017. 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 the gathering, processing and logistics services from our West Coast operations to remain relatively flat in 2017 compared to 2016. Although our West Coast operations’ results have been relatively consistent over the past several years, these operations have not experienced growth as fast or to the degree 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.

•

During 2015, we incurred $8.5 million of impairments of our property, plant and equipment related to our Granite Wash gathering and processing operations, which resulted from decreases in forecasted cash flows for those operations given that our major customer of those assets declared bankruptcy and ceased substantial drilling in the Granite Wash in the near future given current and future anticipated market conditions related to natural gas and NGLs.

•

During 2015, Crestwood Equity incurred a $354.4 million impairment of its property, plant and equipment related to its Barnett gathering and processing operations, which resulted from the actions of our primary customer in the Barnett Shale, Quicksilver Resources, Inc. (Quicksilver), related to its filing for protection under Chapter 11 of the U.S. Bankruptcy Code in 2015. Crestwood Midstream did not record an impairment of its property, plant and equipment related to its gathering and processing assets in the Barnett Shale as the sum of the undiscounted cash flows expected to result from the use of the assets and their eventual disposition exceeded the carrying value of the property, plant and equipment by over 30%. As a result, Crestwood Midstream’s property, plant and equipment exceeds Crestwood Equity’s property, plant and equipment related to its gathering and processing assets in the Barnett Shale.

•

During 2015, we incurred $61.9 million and $45.7 million of impairments of property, plant and equipment related to our Fayetteville and Haynesville gathering and processing operations, respectively, which resulted from decreases in forecasted cash flows for those operations given that our customers for those assets have ceased any substantial drilling in the Fayetteville and Haynesville Shales in the near future given current and future anticipated market conditions related to natural gas.


•	During 2015, we incurred a $31.2 million impairment of our property, plant and equipment related to our Watkins Glen development project in our marketing, supply and logistics operations, which resulted from continued delays and uncertainties in the permitting of our proposed NGL storage facility.

At December 31, 2017, our estimates of fair value considered a number of factors, including the potential value we would receive if we sold the asset, a 12% discount rate and projected cash flows, which is a Level 3 fair value measurement. At December 31, 2015, our estimates of fair value considered a number of factors, including the potential value we would receive if we sold the asset, a 15% discount rate and projected cash flows, which is a Level 3 fair value measurement. 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.

During 2017, 2016 and 2015, 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. 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 the gathering, processing and logistics services from our West Coast operations to remain relatively flat in 2017 compared to 2016. Although our West Coast operations’ results have been relatively consistent over the past several years, these operations have not experienced growth as fast or to the degree 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.


•	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.


•	During 2015, Crestwood Equity fully impaired $238.9 million of its intangible assets related to its Barnett gathering and processing operations, which resulted from the actions of our primary customer in the Barnett Shale, Quicksilver, related to filing for protection under Chapter 11 of the U.S. Bankruptcy Code in 2015.

•

During 2015, we fully impaired $70.9 million and $6.0 million of intangible assets related to our Fayetteville and Haynesville gathering and processing operations, respectively, which resulted from decreases in forecasted cash flows for those operations given that our customers for those assets have ceased any substantial drilling in the Fayetteville and Haynesville Shales in the near future given current and future anticipated market conditions related to natural gas.

At December 31, 2016, our estimates of fair value considered a number of factors, including the potential value we would receive if we sold the asset, a 19% discount rate and projected cash flows, which is a Level 3 fair value measurement. At December 31, 2015, our estimates of fair value considered a number of factors, including the potential value we would receive if we sold the asset, a 15% discount rate and projected cash flows, which is a Level 3 fair value measurement. 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	6 - 8

Assets Held for Sale

We classify assets (or groups of assets) to be disposed of as held for sale when specific criteria have been met. Assets classified as held for sale are recorded at the lower of the carrying value or the estimated fair value less cost to sell of those assets. The fair value is based on the consideration to be received, which is a Level 3 fair value measurement. We cease depreciation and amortization of the assets in the period they are considered held for sale. We classified approximately $3.0 million of property, plant and equipment related to our Marcellus gathering and processing assets as assets held for sale (which is included in prepaid expenses and other current assets) on our consolidated balance sheet at their fair value at December 31, 2017. In addition, we recorded a loss on long-lived assets of approximately $2.5 million during the year ended December 31, 2017 related to these assets. The sale is contingent upon customary approvals and satisfaction of certain other closing conditions, which we believe is probable at December 31, 2017.

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, 2016 and 2015. At December 31, 2017, our accumulated goodwill impairments at CEQP and CMLP were approximately $1,656.5 million and $1,399.3 million, respectively. During 2017, we adopted the provisions of ASU 2017-04, Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment, which allows companies to apply a single test to determine if goodwill is impaired and the amount of any impairment, which is reflected in our 2017 goodwill impairments. The following table summarizes the goodwill of our various reporting units (in millions):



	Goodwill Impairments during the Year Ended December 31, 2015		Goodwill at January 1, 2016		Goodwill Impairments during the Year Ended December 31, 2016		Other				Goodwill at December 31, 2016		Impact of Sale of US Salt				Goodwill Impairments during the Year Ended December 31, 2017		Goodwill at December 31, 2017
G&P
Fayetteville	$	72.5	$	—	$	—	$	—			$	—	$	—			$	—	$	—
Marcellus	—		8.6		8.6		—				—		—				—		—
Arrow	—		45.9		—		—				45.9		—				—		45.9
S&T
Northeast Storage and Transportation	—		726.3		—		(726.3		)	⁽¹⁾	—		—				—		—
COLT	623.4		44.9		44.9		—				—		—				—		—
MS&L																			—
West Coast	85.9		—		—		2.4			⁽²⁾	2.4		—				2.4		—
Supply and Logistics	99.0		167.2		65.5		—				101.7		—				—		101.7
Storage and Terminals	53.7		50.5		14.1		—				36.4		—				36.4		—
US Salt	—		12.6		—		—				12.6		(12.6		)	⁽³⁾	—		—
Trucking	148.4		29.5		29.5		—				—		—				—		—
Watkins Glen	66.2		—		—		—				—		—				—		—
Total CMLP	$	1,149.1	$	1,085.5	$	162.6	$	(723.9	)		$	199.0	$	(12.6	)		$	38.8	$	147.6
Barnett (G&P)	257.2		—		—		—				—		—				—		—
Total CEQP	$	1,406.3	$	1,085.5	$	162.6	$	(723.9	)		$	199.0	$	(12.6	)		$	38.8	$	147.6


(1)	Reflects impact of the deconsolidation of our NE S&T assets in June 2016.


(2)	In December 2016, we acquired four NGL terminals for our MS&L segment for approximately $7.2 million with total goodwill of approximately $2.4 million. This acquisition was not material to our consolidated financial statements as of and for the year ended December 31, 2016.

(3) In December 2017, we sold 100% of our equity interests in US Salt to an affiliate of Kissner Group Holdings LP.

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. Although our West Coast operations’ results have been relatively consistent over the past several years, these operations have not experienced growth as fast or to the degree 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. 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.

The goodwill impairments recorded during 2015 primarily resulted from decreasing forecasted cash flows and increasing the discount rates utilized in determining the fair value of the reporting units considering the continued decrease in commodity prices and its impact on the midstream industry and our customers. We utilized the income approach to determine the fair value of our reporting units given the limited availability of comparable market-based transactions during 2015, and we utilized discount rates ranging from 9% to 12% in 2015 in applying the income approach to determine the fair value of our reporting units with goodwill as of December 31, 2015.

In addition to the goodwill impairments recorded by Crestwood Midstream as reflected in the table above, Crestwood Equity recorded a goodwill impairment of its Barnett reporting unit of approximately $257.2 million in 2015. The impairment primarily resulted from increasing the discount rate utilized in determining the fair value of the reporting unit, considering the actions of its primary customer in the Barnett Shale during 2015, Quicksilver, related to its filing for protection under Chapter 11 of the U.S. Bankruptcy Code in March 2015.

Investment 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.

During 2015, we recorded a $51.4 million and $23.4 million impairment of our Jackalope Gas Gathering Services, L.L.C. (Jackalope) and Powder River Basin Industrial Complex, LLC (PRBIC) equity method investments, respectively, as a result of decreasing forecasted cash flows and increasing the discount rates utilized in determining the fair value of the equity method investments considering the continued decrease in commodity prices and its impact on the midstream industry and our equity method investments’ customers, which is a Level 3 fair value measurement. We did not record impairments of our equity method investments during the years ended December 31, 2017 and 2016.

We estimated the fair value of our equity method investments at December 31, 2015 based on projected cash flows, a 15.5% discount rate and the potential value we would receive if we sold the equity method investment. Estimating projected cash flows requires us to make certain assumptions as it relates to the future operating performance of each of our equity method investments (which includes assumptions, among others, about estimating future operating margins and related future growth in those margins, contracting efforts and the cost and timing of facility expansions) and assumptions related to our equity method investments’ customers, such as 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.

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. The fair value of certain AROs could not be determined as the settlement dates (or range of dates) associated with these assets were not estimable. At December 31, 2017 and 2016, 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. At December 31, 2017 and 2016, our net deferred financing costs were reflected as a reduction of long-term debt on our consolidated balance sheets.

Revenue Recognition

We gather, process, treat, compress, store, transport and sell various commodities (including crude oil, natural gas, NGLs and water) pursuant to fixed-fee and percent-of-proceeds contracts. Under certain of those contracts in our G&P operations and our MS&L operations, we take title to the underlying commodity. We classify the revenues associated with the products to which we take title as product revenues and all other revenues as service revenues in our consolidated statement of operations.

We recognize revenues for these services and products when all of the following criteria are met:

• services have been rendered or products delivered or sold;

• persuasive evidence of an exchange arrangement exists;

• the price for services is fixed or determinable; and

• collectability is reasonably assured.

We record deferred revenue when we receive amounts from our customers but have not met the criteria listed above. We recognize deferred revenue in our consolidated statements of operations when the criteria has been met and all services have been rendered. At December 31, 2017 and 2016, we had deferred revenue of approximately $0.6 million and $7.5 million, which is reflected in accrued expenses and other liabilities on our consolidated balance sheets.

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

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

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

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.

We did not have any derivatives identified as fair value hedges or cash flow hedges for accounting purposes during the years ended December 31, 2017, 2016 or 2015.

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.

New Accounting Pronouncements Issued But Not Yet Adopted

As of December 31, 2017, the following accounting standards had not yet been adopted by us:

Revenue. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers, which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes current revenue recognition guidance. We utilized the modified retrospective method to adopt the provisions of this standard effective January 1, 2018. Upon adoption of the standard we began classifying certain capital expenditure reimbursements from our customers as deferred revenue rather than as reductions of property, plant and equipment in our consolidated financial statements. We reclassified approximately $69.1 million of these net reimbursements to net deferred revenue on January 1, 2018, which primarily resulted in approximately $20.0 million cumulative effect of accounting change being recorded as an increase to partners' capital on January 1, 2018. In addition, the standard requires us to begin classifying service revenues on certain of our gathering and processing contracts as reductions of costs of product sold prospectively beginning January 1, 2018.

Leases. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which revises the accounting for leases by requiring certain leases to be recognized as assets and liabilities on the balance sheet, and requiring companies to disclose additional information about their leasing arrangements. We expect to adopt the provisions of this standard effective January 1, 2019 and are currently evaluating the impact that this standard will have on our consolidated financial statements.

Cash Flows. In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments, which clarifies how certain cash receipts and cash payments are presented and classified in the statement of cash flows. We adopted the provisions of this standard effective January 1, 2018, and the adoption of this standard did not have a material impact on our consolidated financial statements.

Divestitures	12 Months Ended
Divestitures	Dec. 31, 2017
Business Combinations [Abstract]
Acquisitions	Divestiture 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 of approximately $33.6 million from the sale, which was included in gain (loss) on long-lived assets in our consolidated statement of operations. As part of the US Salt divestiture, we retained all surface and sub-surface rights necessary to place the Watkins Glen NGL storage development project into service once we receive all required regulatory approvals. US Salt was previously included in our MS&L segment.

Certain Balance Sheet Information

12 Months Ended

Dec. 31, 2017

Balance Sheet Related Disclosures [Abstract]

Certain Balance Sheet Information

Property, Plant and Equipment

Property, plant and equipment of the following at December 31, 2017 and 2016 (in millions):



	CEQP				CMLP
	December 31,				December 31,
	2017		2016		2017		2016
Gathering systems and pipelines and related assets	$	678.0	$	639.4	$	820.9	$	782.3
Facilities and equipment	1,141.4		1,328.3		1,326.5		1,513.4
Buildings, land, rights-of-way, storage rights and easements	319.1		315.4		322.8		319.1
Vehicles	37.3		45.7		35.5		44.0
Construction in process	87.5		85.9		87.5		85.9
Salt deposits	—		120.5		—		120.5
Office furniture and fixtures	21.9		20.2		22.1		20.3
	2,285.2		2,555.4		2,615.3		2,885.5
Less: accumulated depreciation and depletion	464.4		457.8		607.8		587.1
Total property, plant and equipment, net	$	1,820.8	$	2,097.6	$	2,007.5	$	2,298.4

Depreciation. CEQP’s depreciation expense totaled $135.9 million, $154.8 million and $195.1 million for the years ended December 31, 2017, 2016 and 2015. CMLP’s depreciation expense totaled $150.0 million, $168.9 million and $186.7 million for the years ended December 31, 2017, 2016 and 2015. Depletion expense at both CEQP and CMLP totaled $0.7 million for each of the years ended December 31, 2017, 2016 and 2015.

Capitalized Interest. During the years ended December 31, 2017, 2016 and 2015, CEQP and CMLP capitalized interest of $2.9 million, $0.7 million and $2.5 million related to certain expansion projects.

Gain (Loss) on Long-Lived Assets. During the year ended December 31, 2017, we recorded a gain of approximately $33.6 million on the sale of our 100% interest in US Salt. In addition, we recorded a loss of approximately $14.4 million during the year ended December 31, 2017, related to the retirement and/or disposition of certain of our Marcellus and Arrow gathering and processing assets.

Intangible Assets

Intangible assets consisted of the following at December 31, 2017 and 2016 (in millions):



	CEQP				CMLP
	December 31,				December 31,
	2017		2016		2017		2016
Customer accounts	$	438.9	$	541.9	$	438.9	$	541.9
Covenants not to compete	—		1.0		—		1.0
Gas gathering, compression and processing contracts	325.2		325.2		325.2		325.2
Trademarks	24.7		30.5		9.2		15.0
	788.8		898.6		773.3		883.1
Less: accumulated amortization	191.6		241.2		177.6		230.2
Total intangible assets, net	$	597.2	$	657.4	$	595.7	$	652.9

The following table summarizes total accumulated amortization of our intangible assets at December 31, 2017 and 2016 (in millions):



	CEQP				CMLP
	December 31,				December 31,
	2017		2016		2017		2016
Customer accounts	$	89.8	$	162.4	$	89.8	$	162.4
Gas gathering, compression and processing contracts	82.0		63.2		82.0		63.2
Trademarks	19.8		15.6		5.8		4.6
Total accumulated amortization	$	191.6	$	241.2	$	177.6	$	230.2

Crestwood Equity’s amortization expense related to its intangible assets for the years ended December 31, 2017, 2016 and 2015, was approximately $53.7 million, $72.5 million and $102.8 million. Crestwood Midstream’s amortization expense related to its intangible assets for the years ended December 31, 2017, 2016 and 2015 was approximately $50.6 million, $69.3 million and $89.6 million.

Estimated amortization of our intangible assets for the next five years is as follows (in millions):



	CEQP		CMLP
Year Ending December 31,
2018	$	43.4	$	42.0
2019	41.7		41.7
2020	41.7		41.7
2021	41.7		41.7
2022	41.7		41.7

Accrued Expenses and Other Liabilities

Accrued expenses and other liabilities consisted of the following at December 31, 2017 and 2016 (in millions):



	CEQP				CMLP
	December 31,				December 31,
	2017		2016		2017		2016
Accrued expenses	$	56.6	$	46.5	$	55.5	$	45.1
Accrued property taxes	4.8		4.2		4.8		4.2
Accrued natural gas purchases	—		4.9		—		4.9
Income tax payable	0.3		1.6		0.3		0.4
Interest payable	20.3		22.8		20.3		22.8
Accrued additions to property, plant and equipment	22.3		1.7		22.2		1.7
Capital leases	1.0		1.3		1.0		1.3
Deferred revenue	0.6		7.5		0.6		7.5
Total accrued expenses and other liabilities	$	105.9	$	90.5	$	104.7	$	87.9

Asset Retirement Obligations

12 Months Ended

Dec. 31, 2017

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, 2017 and 2016 (in millions):



	December 31,
	2017			2016
Net asset retirement obligation at January 1	$	27.8		$	26.4
Liabilities incurred	—			1.0
Liabilities settled	(1.2		)	(1.2		)
Accretion expense	1.4			1.6
Change in estimate	(0.5		)	—
Net asset retirement obligation at December 31	$	27.5		$	27.8

We did not have any material assets that were legally restricted for use in settling asset retirement obligations as of December 31, 2017 and 2016.

Investments in Unconsolidated Affiliates

12 Months Ended

Dec. 31, 2017

Equity Method Investments and Joint Ventures [Abstract]

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,
	2017			2017		2016			2017		2016				2015
Stagecoach Gas Services LLC	50.00	%		$	849.8	$	871.0		$	25.3	$	15.9			$	—
Jackalope Gas Gathering Services, L.L.C.	50.00	%	⁽¹⁾	184.9		197.2			10.5		20.8				(43.4		)	⁽³⁾
Crestwood Permian Basin Holdings LLC	50.00	%		102.0		(0.5		)	8.4		(0.5		)		—
Tres Palacios Holdings LLC	50.01	%		37.8		39.0			2.2		(0.3		)		2.5
Powder River Basin Industrial Complex, LLC⁽²⁾	50.01	%		8.5		8.7			1.4		(4.4		)	⁽³⁾	(19.9		)	⁽³⁾
Total				$	1,183.0	$	1,115.4		$	47.8	$	31.5			$	(60.8	)


(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)	During the year ended December 31, 2015, we recorded additional equity earnings of approximately $3.2 million related to a gain associated with the adjustment of our member’s capital account by our equity investee.

(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. During the year ended December 31, 2015, we recorded impairments of our PRBIC and Jackalope equity investments of approximately $23.4 million and $51.4 million. For a further discussion of these impairments, see Note 2.

Description of Investments

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.

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 approximately 100,000 acres and 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 currently estimated to cost $180 million, of which approximately $84.3 million has been spent through December 31, 2017) 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, 2017 and 2016.

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 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 has agreed to contribute to Crestwood Permian the first $151 million of capital costs required to fund the expansion of the Delaware Basin assets, which includes a new processing plant located in Orla, Texas and associated pipelines (Orla processing plant).

Stagecoach Gas Services LLC

On June 3, 2016, Crestwood Northeast and CEGP formed Stagecoach Gas to own and further develop our NE S&T assets. During 2016, we contributed to Stagecoach Gas the entities owning the 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 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.

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. Although Stagecoach Gas anticipates that these growth capital projects will be constructed in the future, it does not expect that these projects will produce meaningful operating results prior to December 31, 2020. As a result, at December 31, 2017, we recorded a liability of $57 million for this obligation, which is reflected in other long-term liabilities on our consolidated balance sheet and in loss on contingent consideration in our consolidated income statement for the year ended December 31, 2017.

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.

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.

Powder River Basin Industrial Complex, LLC

Crestwood Crude Logistics LLC (Crude Logistics), 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.

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,
	2017										2016
	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⁾	$	55.1	$	1,765.4	$	7.0	$	1.4	$	1,812.1	$	57.0	$	1,807.6	$	6.0	$	4.1	$	1,854.5
Other⁽²⁾⁽³⁾	81.3		801.1		53.4		93.6		735.4		50.4		708.5		23.2		74.4		661.3
Total	$	136.4	$	2,566.5	$	60.4	$	95.0	$	2,547.5	$	107.4	$	2,516.1	$	29.2	$	78.5	$	2,515.8


(1)	As of December 31, 2017, our equity in the underlying net assets of Stagecoach Gas exceeded our investment balance by approximately $51.4 million. This excess amount is entirely attributable to goodwill and, as such, is not subject to amortization. Our Stagecoach Gas investment is included in our storage and transportation segment.

(2)

Includes our Jackalope, Tres Holdings, PRBIC and Crestwood Permian investments. As of December 31, 2017, our equity in the underlying net assets of Jackalope, Tres Holdings, PRBIC and Crestwood Permian exceeded our investment balance by approximately $0.7 million, $26.5 million, $6.4 million and $11.6 million, respectively. Our Tres Holdings and PRBIC investments are included in our storage and transportation segment and our Jackalope and Crestwood Permian investments are included in our gathering and processing segment.

(3)

On June 21, 2017, we contributed to Crestwood Permian 100% of the equity interest of Crestwood 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 requires Crestwood Permian to record the assets and liabilities of Crestwood New Mexico at our historical book value. The difference between our equity in Crestwood New Mexico’s net assets and our investment balance is not subject to amortization.

Operating Results Data



	Year Ended December 31,
	2017						2016						2015
	Operating Revenues		Operating Expenses		Net Income		Operating Revenues		Operating Expenses		Net Income		Operating Revenues		Operating Expenses		Net Income
Stagecoach	$	168.6	$	77.7	$	91.1	$	99.3	$	44.1	$	55.3	$	—	$	—	$	—
Other⁽¹⁾	181.8		143.6		38.9		127.6		113.9		13.5		104.7		79.5		24.9
Total	$	350.4	$	221.3	$	130.0	$	226.9	$	158.0	$	68.8	$	104.7	$	79.5	$	24.9

(1)

Includes our Jackalope, Tres Holdings, PRBIC and Crestwood Permian 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 both the years ended December 31, 2017 and 2016, and $3.0 million for the year ended December 31, 2015, 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, 2017, 2016 and 2015, 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 $0.6 million and $1.6 million for the years ended December 31, 2017 and 2016, which we amortize over the life of PRBIC’s property, plant and equipment and its agreement with Chesapeake.

Distributions and Contributions



	Distributions						Contributions
	Year Ended December 31,						Year Ended December 31,
	2017		2016		2015		2017		2016		2015
Stagecoach Gas	$	47.3	$	16.0	$	—	$	0.8	$	—	$	—
Jackalope⁽¹⁾	26.3		27.4		12.5		3.5		1.4		25.4
Tres Holdings⁽²⁾	9.0		8.5		7.4		5.6		11.0		5.7
PRBIC⁽¹⁾	1.6		2.0		1.9		—		—		10.7
Crestwood Permian⁽³⁾	23.4		—		—		117.5		—		—
Total	$	107.6	$	53.9	$	21.8	$	127.4	$	12.4	$	41.8

(1) Jackalope and PRBIC are required to make quarterly distributions of its available cash to its members based on their respective ownership percentage. We

received a cash distribution of $7.4 million from Jackalope in January 2018, and we received a cash distribution of $0.3 million from PRBIC in February

2018.

(2) 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.

(3) 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.

Stagecoach Gas. Stagecoach Gas is required, within 30 days following the end of each quarter, to distribute 65% and 35% of its available cash (as defined in its limited liability company agreement) to CEGP and us, respectively. 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 2018, we received a cash distribution from Stagecoach Gas of approximately $11.3 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 will receive 100% of Crestwood New Mexico's available cash (as defined in the limited liability company agreement) until the earlier of the Orla processing plant in-service date or June 30, 2018, at which time the distributions will be 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 2018, we received a cash distribution from Crestwood Permian of approximately $4.3 million.

Risk Management

12 Months Ended

Dec. 31, 2017

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

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. During the years ended December 31, 2017, 2016 and 2015, the impact to our consolidated statements of operations related to our commodity-based derivatives reflected in costs of product/services sold was a loss of $31.2 million, a loss of $7.8 million and a gain of $18.9 million, respectively. 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, 2017		December 31, 2016
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, crude and heating oil (MMBbls)	15.3	17.5	13.1	15.1
Natural gas (MMcf)	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 34 months or less; however, 88% of the contracted volumes will be delivered or settled within 12 months.

Credit Risk

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. The aggregate fair value of all commodity derivative instruments with credit-risk-related contingent features that were in a liability position at December 31, 2017 and 2016, was $28.9 million and $13.9 million. At December 31, 2017 and 2016, we posted less than $0.1 million of collateral for our commodity derivative instruments with credit-risk-related contingent features. In addition, at December 31, 2017 and 2016, we had a New York Mercantile Exchange (NYMEX) related net derivative asset position of $27.2 million and $14.3 million, for which we posted $5.6 million and $4.2 million of cash collateral in the normal course of business. At December 31, 2017 and 2016, we also received collateral of $3.7 million and $4.3 million in the normal course of business. 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.

Fair Value Measurements

12 Months Ended

Dec. 31, 2017

Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]

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, 2017 and 2016, the carrying amounts of cash, accounts receivable and accounts payable approximate fair value based on the short-term nature of these instruments.

Credit Facility

The fair value of the amounts outstanding under our CMLP credit facility approximates the carrying amounts as of December 31, 2017 and 2016, 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 value (reduced for deferred financing costs associated with the respective notes) and fair value of our senior notes (in millions):



	December 31, 2017				December 31, 2016
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
2020 Senior Notes	$	—	$	—	$	340.6	$	350.2
2022 Senior Notes	$	—	$	—	$	429.3	$	447.3
2023 Senior Notes	$	692.1	$	728.8	$	690.6	$	722.6
2025 Senior Notes	$	492.3	$	517.9	$	—	$	—

Financial Assets and Liabilities

As of December 31, 2017 and 2016, 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, 2017 and 2016 (in millions):



	December 31, 2017
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting⁽¹⁾			Collateral/Margin Received or Paid			Recorded in Balance Sheet
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

	December 31, 2016
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting⁽¹⁾			Collateral/Margin Received or Paid			Recorded in Balance Sheet
Assets
Assets from price risk management	$	0.6	$	84.4	$	—	$	85.0	$	(67.8	)	$	(10.9	)	$	6.3
Suburban Propane Partners, L.P. units⁽²⁾	4.3		—		—		4.3		—			—			4.3
Total assets at fair value	$	4.9	$	84.4	$	—	$	89.3	$	(67.8	)	$	(10.9	)	$	10.6

Liabilities
Liabilities from price risk management	$	2.7	$	90.2	$	—	$	92.9	$	(67.8	)	$	3.5		$	28.6
Total liabilities at fair value	$	2.7	$	90.2	$	—	$	92.9	$	(67.8	)	$	3.5		$	28.6


(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

12 Months Ended

Dec. 31, 2017

Text Block [Abstract]

Long-Term Debt

Long-term debt consisted of the following at December 31, 2017 and 2016, (in millions):



	December 31,
	2017		2016
Credit Facility	$	318.2	$	77.0
2020 Senior Notes	—		338.8
Fair value adjustment of 2020 Senior Notes	—		1.8
2022 Senior Notes	—		436.4
2023 Senior Notes	700.0		700.0
2025 Senior Notes	500.0		—
Other	2.4		3.7
Less: deferred financing costs, net	28.4		34.0
Total debt	1,492.2		1,523.7
Less: current portion	0.9		1.0
Total long-term debt, less current portion	$	1,491.3	$	1,522.7

Credit Facility

Crestwood Midstream’s amended and restated senior secured credit agreement (the CMLP Credit Agreement) provides for a five-year $1.5 billion revolving credit facility (the CMLP Credit Facility), which expires in September 2020 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 $1.5 billion credit agreement.

Prior to amending and restating its credit agreement in September 2015, Crestwood Midstream had a five-year $1.0 billion senior secured revolving credit facility, which would have expired October 2018. In conjunction with the closing of the Simplification Merger, Crestwood Midstream borrowed approximately $720.0 million under the CMLP Credit Facility on September 30, 2015 to (i) repay all borrowings outstanding under the $1.0 billion credit facility; (ii) fund a distribution to the Company of approximately $378.3 million for purposes of repaying (or, if applicable, satisfying and discharging) substantially all of the Company’s outstanding indebtedness as discussed above; and (iii) pay merger-related fees and expenses. We recognized a loss on extinguishment of debt of approximately $1.8 million for the year ended December 31, 2015 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 0.75% to 1.75% 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 1.75% to 2.75% 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 0.30% to 0.50% 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, 2017, Crestwood Midstream had $499.3 million of available capacity under its credit facility considering the most restrictive covenants in its credit agreement. At December 31, 2017 and 2016, Crestwood Midstream’s outstanding standby letters of credit were $52.2 million and $64.0 million. Interest rates under the CMLP Credit Facility were between 3.94% and 6.00% at December 31, 2017 and 3.21% and 5.25% at December 31, 2016. The weighted-average interest rate on outstanding borrowings as of December 31, 2017 and 2016 was 4.11% and 3.23%.

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, 2017, the net debt to consolidated EBITDA was approximately 4.14 to 1.0, the consolidated EBITDA to consolidated interest expense was approximately 4.14 to 1.0, and the senior secured leverage ratio was 0.86 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

2020 Senior Notes. The 6.0% Senior Notes due 2020 (the 2020 Senior Notes) were scheduled to mature on December 15, 2020, and interest was payable semi-annually in arrears on June 15 and December 15 of each year. The fair value adjustment was being amortized over the remaining life of the 2020 Senior Notes.

2022 Senior Notes. The 6.125% Senior Notes due 2022 (the 2022 Senior Notes) were scheduled to mature on March 1, 2022, and interest was payable semi-annually on March 1 and September 1 of each year.

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.

In March 2016, Crestwood Midstream filed a registration statement with the SEC under which it offered to exchange the 2023 Senior Notes for any and all outstanding 2023 Senior Notes. Crestwood Midstream completed the exchange offer in July 2016. The terms of the exchange notes are substantially identical to the terms of the 2023 Senior Notes, except that the exchange notes are freely tradable.

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 outstanding under the 2020 Senior Notes and the 2022 Senior Notes 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 noted 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, 2017, 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 $2,195.4 million as of December 31, 2017.

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 amount outstanding under the 2020 Senior Notes and 2022 Senior Notes, 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 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 2022 Senior Notes); and (ii) paid $5.1 million and $1.0 million of accrued interest on the 2020 Senior Notes and 2022 Senior Notes, 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 amount outstanding under the 2020 Senior Notes and 2022 Senior Notes, respectively, utilizing a portion of the proceeds received from Stagecoach Gas, as further discussed in Notes 2 and 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 the 2020 Senior Notes and 2022 Senior Notes, respectively, on the date they were tendered.

In April 2015, we retired our $350 million 7.75% Senior Notes due 2019 for approximately $364.1 million, including accrued interest of $0.5 million and a call premium of $13.6 million. In conjunction with the redemption of these notes, we recorded a loss on extinguishment of debt of approximately $17.1 million during the year ended December 31, 2015.

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 $2.7 million and $4.2 million in total payments due under agreements, less unamortized discount based on imputed interest of $0.3 million and $0.5 million at December 31, 2017 and 2016, respectively.

Maturities

The aggregate maturities of principal amounts on our outstanding long-term debt and other notes payable as of December 31, 2017 for the next five years and in total thereafter are as follows (in millions):



2018	$	0.9
2019	0.9
2020	318.4
2021	0.2
2022	0.2
Thereafter	1,200.0
Total debt	$	1,520.6

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. Under the support agreement, in the event the SPH Issuers fail to pay any principal amount of the supported debt when due, Crestwood Equity will pay the holders of the supported debt, or the SPH Issuers for the benefit of the holders of the supported debt, an amount up to the principal amount of the supported debt that the SPH Issuers have failed to pay. Crestwood Equity has no obligation to make a payment under the support agreement with respect to any accrued and unpaid interest or any redemption premium or other costs, fees, expenses, penalties, charges or other amounts of any kind that shall be due to the noteholders by the SPH Issuers, whether on or related to the supported debt or otherwise. The support agreement terminates on the earlier of the date the supported debt is extinguished or on the maturity date of supported debt or any permitted refinancing thereof. We believe the probability of any future payment on this residual value guarantee is remote.

Earnings Per Limited Partner Unit	12 Months Ended
Earnings Per Limited Partner Unit	Dec. 31, 2017
Earnings Per Share [Abstract]
Earnings Per Limited Partner Unit	Earnings Per Limited Partner Unit Our net income (loss) attributable to Crestwood Equity 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 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 per limited partner unit is anti-dilutive. During the years ended December 31, 2017, 2016 and 2015, we excluded a weighted-average of 7,007,917, 6,433,127 and 1,547,060 common units (representing preferred units), a weighted-average of 438,789 common units in all periods (representing subordinated units), and a weighted-average of 7,146,663, 7,548,624 and 2,760,794 common units (representing Crestwood Niobrara’s preferred units). See Note 12 for additional information regarding the potential conversion of our preferred units and Crestwood Niobrara’s preferred units to common units. CEQP Reverse Split. On October 22, 2015, the board of directors of CEQP’s general partner approved a 1-for-10 reverse split on our common units, effective after the market closed on November 23, 2015. The units began trading on a split-adjusted basis on November 24, 2015. Pursuant to the reverse split, common unit holders received one common unit for every 10 common units owned with substantially the same terms and conditions of the common units prior to the reverse split.

Income Taxes

12 Months Ended

Dec. 31, 2017

Income Tax Disclosure [Abstract]

Income Taxes

The (provision) benefit for income taxes for the years ended December 31, 2017, 2016, and 2015 consisted of the following (in millions):



	CEQP									CMLP
	Year Ended December 31,									Year Ended December 31,
	2017			2016			2015			2017⁽¹⁾		2016			2015
Current:
Federal	$	(1.1	)	$	(3.2	)	$	(1.6	)	$	—	$	—		$	—
State	(0.2		)	(0.2		)	(0.6		)	—		0.2			(0.3		)
Total current	(1.3		)	(3.4		)	(2.2		)	—		0.2			(0.3		)
Deferred:
Federal	2.1			3.0			2.9			—		—			—
State	—			0.1			0.7			—		(0.2		)	0.3
Total deferred	2.1			3.1			3.6			—		(0.2		)	0.3
(Provision) benefit for income taxes	$	0.8		$	(0.3	)	$	1.4		$	—	$	—		$	—


(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, 2017, 2016 and 2015, 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 reflect 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. For the year ended December 31, 2017, we decreased our net deferred tax liability by $1.3 million to reflect the reduction of corporate tax rates under the Tax Cuts and Jobs Act.

Components of our deferred income taxes at December 31, 2017 and 2016 are as follows (in millions).



	CEQP						CMLP
	December 31,						December 31,
	2017			2016			2017			2016
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 acquired company	(3.5		)	(5.5		)	(0.7		)	(0.7		)
Total deferred tax liability	(3.5		)	(5.5		)	(0.7		)	(0.7		)
Net deferred tax liability	$	(3.3	)	$	(5.3	)	$	(0.7	)	$	(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, 2017, 2016 and 2015 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

12 Months Ended

Dec. 31, 2017

Partners' Capital [Abstract]

Partners' Capital

Partners’ Capital

Simplification Merger. As discussed in Note 1, on September 30, 2015, we completed the Simplification Merger. As part of the merger consideration, Crestwood Midstream’s common and preferred unitholders (other than Crestwood Equity and its subsidiaries) received 2.75 common or preferred units of CEQP for each common or preferred unit of CMLP held upon completion of the merger.

Prior to the Simplification Merger, CEQP indirectly owned a non-economic general partnership interest in Crestwood Midstream and 100% of its IDRs. Crestwood Midstream was also a publicly-traded limited partnership with common units listed on the NYSE. However, as a result of our completion of the Simplification Merger on September 30, 2015, Crestwood Midstream’s common units ceased to be listed on the NYSE, its IDRs were eliminated and Crestwood Midstream became a wholly-owned subsidiary of CEQP.

Preferred Units

Pursuant to Crestwood Midstream’s agreements with a group of investors, including Magnetar Financial, affiliates of GSO Capital Partners LP and GE Energy Financial Services (the Class A Purchasers), Crestwood Midstream agreed to sell to the Class A Purchasers and the Class A Purchasers agreed to purchase from Crestwood Midstream up to $500 million of Class A Preferred Units (CMLP Preferred Units) at a fixed price of $25.10 per unit on or before September 30, 2015. In August 2015, the Class A Purchasers acquired from Crestwood Midstream the remaining $60.0 million of CMLP Preferred Units for net proceeds of approximately $58.8 million after deducting transaction fees and offering expenses.

As discussed above, in conjunction with the closing of the Simplification Merger, 21,580,244 of CMLP Preferred Units were exchanged for 59,345,672 new preferred units of CEQP (the Preferred Units) with substantially similar terms and conditions to those of the CMLP Preferred Units and as a result, Crestwood Equity classified the new preferred units as a component of partners’ capital as of December 31, 2015. Because the fair value of the preferred units was materially equivalent immediately before and after the exchange, Crestwood Equity recorded CEQP’s preferred units at Crestwood Midstream’s historical book value.

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 unit holders 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

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 will pay the Managers an aggregate fee of up to 2.0% (which totaled $0.3 million during the year ended December 31, 2017) of the gross sales price per common unit sold under our ATM equity distribution program. The table below shows the units issued and the net proceeds from the issuances:



Issuance Dates	Common Units	Net Proceeds⁽¹⁾ (in millions)
Third Quarter 2017	437,518	$	10.6
Fourth Quarter 2017	195,753	4.6
Total 2017	633,271	$	15.2


(1)	The net proceeds from sales under the ATM program are used for general partnership purposes, which may include debt repayments and capital expenditures.

Distributions

Crestwood Equity

Description. 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).

Limited Partners. A summary of CEQP’s limited partner quarterly cash distributions for the years ended December 31, 2017, 2016 and 2015 is presented below:



Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
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
2015
February 6, 2015	February 13, 2015	$	1.375	$	25.8
May 8, 2015	May 15, 2015	$	1.375	25.7
August 7, 2015	August 14, 2015	$	1.375	25.7
November 6, 2015	November 13, 2015	$	1.375	94.3
				$	171.5

On February 14, 2018, we paid a distribution of $0.60 per limited partner unit to unitholders of record on February 7, 2018 with respect to the fourth quarter of 2017.

Preferred Unit Holders. 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. Through and for the quarter ended June 30, 2017, we paid distributions on our Preferred Units through the issuance of additional Preferred Units. 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 Unit holders. If we fail to pay the full amount payable to our Preferred Unit holders 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, 2017, 2016 and 2015, we issued 4,724,030, 5,815,170 and 1,372,573 Preferred Units to our preferred unit holders in lieu of paying quarterly cash distributions of $43.1 million, $53.0 million and $12.5 million. In November 2017, we made a cash distribution to our preferred unit holders of approximately $15.0 million for the quarter ended September 30, 2017. On February 14, 2018, we made a cash distribution of approximately $15.0 million to our preferred unit holders for the quarter ended December 31, 2017.

On June 9, 2016, Crestwood Equity filed a shelf registration statement with the SEC under which holders of the Preferred Units may sell the common units into which the Preferred Units are convertible. The registration statement became effective on June 15, 2016. Crestwood Equity registered 7,290,552 common units under the registration statement.

Crestwood Midstream

Description. Prior to the completion of the Simplification Merger, Crestwood Midstream’s partnership agreement required the partnership to distribute, within 45 days after the end of each quarter, all available cash (as defined in its partnership agreement) to unitholders of record on the applicable record date. The general partner was not entitled to distributions on its non-economic general partner interest.

In conjunction with the Simplification Merger, Crestwood Midstream amended and restated its partnership agreement. 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.

General Partner. During the year ended December 31, 2015, Crestwood Midstream paid cash distributions to its general partner (representing IDRs and distributions related to common units held by the general partner) of approximately $31.4 million.

On September 30, 2015, Crestwood Midstream made a distribution of approximately $378.3 million to CEQP for purposes of repaying substantially all of its outstanding indebtedness. The distribution was funded with borrowings under the CMLP Credit Facility. In addition, during the years ended December 31, 2017, 2016 and 2015, Crestwood Midstream made distributions of $174.0 million, $227.6 million and $175.6 million, which represented net amounts due to Crestwood Midstream related to cash advances to CEQP for its general corporate activities.

Limited Partners. The following table presents quarterly cash distributions paid to Crestwood Midstream’s limited partners (excluding distributions paid to its general partner on its common units held) during the year ended December 31, 2015.



Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2015
February 6, 2015	February 13, 2015	$	0.41	$	74.3
May 8, 2015	May 15, 2015	$	0.41	74.3
August 7, 2015	August 14, 2015	$	0.41	74.3
				$	222.9

Class A Preferred Unit Holders. Prior to the Simplification Merger, Crestwood Midstream’s partnership agreement required Crestwood Midstream to make quarterly distributions to its Class A Preferred Unit holders. The holders of the Preferred Units were entitled to receive fixed quarterly distributions of $0.5804 per unit. For the 12 quarters following the quarter ended June 30, 2014 (the Initial Distribution Period), distributions on our Preferred Units could be made in additional Preferred Units, cash, or a combination thereof, at our election. If Crestwood Midstream elected to pay the quarterly distribution through the issuance of additional Preferred Units, the number of units to be distributed were calculated as the fixed quarterly distribution of $0.5804 per unit divided by the cash purchase price of $25.10 per unit. Crestwood Midstream 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 are distributed.

Non-Controlling Partners

Crestwood Midstream Class A Preferred Units

As discussed above, prior to the Simplification Merger, Crestwood Equity classified the Crestwood Midstream Class A Preferred Units as a component of Interest of Non-Controlling Partners in its consolidated financial statements.

Crestwood Niobrara Preferred Interest

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.

Net Income (Loss) Attributable to Non-Controlling Partners

The components of net income (loss) attributable to non-controlling partners for the years ended December 31, 2017, 2016 and 2015 are as follows (in millions):



	Year Ended December 31,
	2017		2016		2015
Crestwood Niobrara preferred interests	$	25.3	$	24.2	$	23.1
CMLP net income attributable to non-controlling partners	25.3		24.2		23.1
Crestwood Midstream limited partner interests	—		—		(683.0		)
Crestwood Midstream Class A preferred units	—		—		23.1
CEQP net income (loss) attributable to non-controlling partners	$	25.3	$	24.2	$	(636.8	)

Distributions to Non-Controlling Partners

Crestwood Midstream Limited Partners. Prior to the completion of the Simplification Merger, the Crestwood Midstream partnership agreement required it to distribute, within 45 days after the end of each quarter, all available cash (as defined in its partnership agreement) to unitholders of record on the applicable record date. Crestwood Equity was not entitled to distributions on its non-economic general partner interest in Crestwood Midstream. Crestwood Midstream paid cash distributions to its limited partners (excluding distributions to its general partner) of $222.9 million during the year ended December 31, 2015.

Crestwood Midstream Class A Preferred Unitholders. During the year ended December 31, 2015, Crestwood Midstream issued 1,271,935 Preferred Units to its preferred unitholders in lieu of paying a cash distribution of approximately $31.9 million.

Crestwood Niobrara Preferred Unitholders. Crestwood Niobrara is required to make quarterly distributions to GE within 30 days after the end of each quarter. Beginning with the distribution for the first quarter of 2015, Crestwood Niobrara no longer had the option to pay distributions to GE by issuing additional preferred units in lieu of paying a cash distribution. On January 30, 2015, Crestwood Niobrara issued 3,680,570 preferred units to GE in lieu of paying a cash distribution for the quarter ended December 31, 2014. During the years ended December 31, 2017, 2016 and 2015, Crestwood Niobrara paid cash distributions of $15.2 million, $15.2 million and $11.3 million to GE.

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

12 Months Ended

Dec. 31, 2017

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, 2017, 2016 and 2015.



	Units		Weighted-Average Grant Date Fair Value
Unvested - January 1, 2015	131,588		$	132.10
Vested - restricted units	(91,798	)	$	121.13
Vested - phantom units	(4,856	)	$	67.10
Granted - restricted units	142,255		$	55.25
Granted - phantom units	42,349		$	62.31
Modification - restricted units	226,401		$	68.85
Modification - phantom units	41,269		$	58.36
Forfeited ⁽¹⁾	(20,994	)	$	89.97
Unvested - December 31, 2015	466,214		$	69.80
Vested - restricted units	(193,295	)	$	76.82
Granted - restricted units	1,067,535		$	14.58
Granted - phantom units	17,467		$	15.54
Forfeited	(65,591	)	$	25.13
Unvested - December 31, 2016	1,292,330		$	24.67
Vested - restricted units	(607,115	)	$	28.00
Vested - performance units	(31,106	)	$	30.27
Granted - restricted units	919,411		$	25.69
Granted - phantom units	15,849		$	25.02
Granted - performance units	405,620		$	30.21
Forfeited - restricted units	(140,137	)	$	23.73
Forfeited - performance units	(24,756	)	$	30.45
Unvested - December 31, 2017	1,830,096		$	25.21


(1)	We implemented a company-wide initiative to reduce operating costs in 2015 and beyond, which included a reduction in workforce. As a result, 7,263 restricted units were forfeited during the year ended December 31, 2015.

As of December 31, 2017 and 2016, we had total unamortized compensation expense of approximately $23.7 million and $14.9 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 $22.4 million, $16.0 million and $11.5 million under the Crestwood LTIP during the years ended December 31, 2017, 2016 and 2015, which is included in general and administrative expenses on our consolidated statements of operations. As of February 12, 2018, we had 3,428,811 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, 2017, 2016, and 2015 we withheld 206,600, 57,508 and 26,095 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 Benefit Plan	12 Months Ended
Employee Benefit Plan	Dec. 31, 2017
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 $18,000 in 2017, 2016 and 2015. 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 $4.0 million, $3.8 million and $4.0 million during the years ended December 31, 2017, 2016 and 2015.

Commitments and Contingencies

12 Months Ended

Dec. 31, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Legal Proceedings

California Trucking Lawsuit. On March 13, 2017, a former Crestwood truck driver filed a lawsuit in the Superior 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 plaintiffs currently include a total of 13 former and current Company drivers, however they are seeking to certify this lawsuit as a class action, which could potentially include approximately 150 drivers. Although our insurance policies would not cover this action, we believe we have meritorious defenses to this lawsuit and will vigorously defend ourselves. We are unable to predict the outcome or to estimate a reasonably possible loss or range of loss for this matter.

General. We are periodically involved in litigation proceedings. If we determine that a negative outcome is probable and the amount of loss is reasonably estimable, then we accrue the estimated amount. The results of litigation proceedings cannot be predicted with certainty. We could incur judgments, enter into settlements or revise our expectations regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations or cash flows in the period in which the amounts are paid and/or accrued. As of December 31, 2017 and 2016, both CEQP and CMLP had approximately $2.1 million and less than $0.1 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 October 2014, we received data requests from the EPA related to the 2014 water releases and we responded to the requests during the first half of 2015. In April 2015, the EPA issued a Notice of Potential Violation (NOPV) under the Clean Water Act relating to the 2014 water releases. We responded to the NOPV in May 2015 and in April 2017, we entered into an Administrative Order on Consent (the Order) with the EPA. The Order requires us to continue to remediate and monitor the impacted area for no less than four years unless all goals of the Order are satisfied earlier. On December 13, 2017, the EPA and Crestwood signed a Combined Complaint and Consent Agreement (CCCA) whereby we agreed to pay a civil penalty of $49,000 to the EPA and purchase emergency response equipment at an estimated cost of approximately $173,000 for the Three Affiliated Tribes as a Supplemental Environmental Project (SEP). The CCCA and SEP concludes the EPA’s penalty phase related to this matter.

On March 3, 2015, we received a grand jury subpoena from the United States Attorney’s Office in Bismarck, North Dakota, seeking documents and information relating to the largest of the three 2014 water releases. We provided the requested information during the second quarter of 2015 and key employees were interviewed by the United States’ Attorney in December

2015. On September 13, 2017, we received a notice from the United States Department of Justice that it completed the

investigation with no charges being filed against us.

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, upon our posting of a performance bond for the amount contemplated by the notice, and pending the outcome of settlement discussions with the EPA related to the NOPV. 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, 2017.

At December 31, 2017 and 2016, our accrual of approximately $1.9 million and $2.1 million is based on our undiscounted estimate of amounts we will spend on compliance with environmental and other regulations, and any associated fines or penalties. We estimate that our potential liability for reasonably possible outcomes related to our environmental exposures (including the Arrow water releases described above) could range from approximately $1.9 million to $3.1 million at December 31, 2017.

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. At December 31, 2017 and 2016, CEQP’s self-insurance reserves were $13.6 million and $15.6 million. We estimate that $9.1 million of this balance will be paid subsequent to December 31, 2018. As such, CEQP has classified $9.1 million in other long-term liabilities on its consolidated balance sheet at December 31, 2017. At December 31, 2017 and 2016, CMLP’s self-insurance reserves were $11.6 million and $12.2 million. CMLP estimates that $7.6 million of this balance will be paid subsequent to December 31, 2018. As such, CMLP has classified $7.6 million in other long-term liabilities on its consolidated balance sheet at December 31, 2017.

Commitments and Purchase Obligations

Operating Leases. We also 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 2018 until 2032.

Future minimum lease payments under our noncancelable operating leases for the next five years ending December 31 and in total thereafter consist of the following (in millions):



Year Ending December 31,
2018	$	35.2
2019	30.1
2020	23.2
2021	11.5
2022	7.7
Thereafter	18.8
Total minimum lease payments	$	126.5

Our rent expense for operating leases for the years ended December 31, 2017, 2016 and 2015, totaled $34.2 million, $25.5 million and $37.4 million.

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, 2017, the total of these firm purchase commitments was $479.3 million, substantially all of which 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 G&P segment. At December 31, 2017, our total purchase commitments were approximately $63.9 million, which primarily relate to future growth projects and maintenance obligations in our G&P 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, and for a further description of our guarantees associated with our assets or businesses we have sold, see Note 9.

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, 2017, we have no amounts accrued for these guarantees.

Related Party Transactions

12 Months Ended

Dec. 31, 2017

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. 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. 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 charged to Stagecoach Gas under this agreement are reflected as operations and maintenance expenses charged by 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 expense charged by 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 of 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 expense charged by 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, 2017, 2016 and 2015 (in millions):



	Year Ended December 31,
	2017			2016			2015
Gathering and processing revenues at CEQP and CMLP	$	1.8		$	2.6		$	3.9
Gathering and processing costs of product sold at CEQP and CMLP⁽¹⁾	$	15.3		$	17.7		$	28.9
Operations and maintenance expenses charged at CEQP and CMLP⁽²⁾	$	22.3		$	8.1		$	3.3
General and administrative expenses charged by CEQP to CMLP, net⁽³⁾	$	19.4		$	13.0		$	49.5
General and administrative expenses at CEQP charged to (from) Crestwood Holdings, net⁽⁴⁾	$	(1.7	)	$	(2.2	)	$	0.4

(1) Represents natural gas purchases from Sabine Oil and Gas, an affiliate of Crestwood Holdings.

(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, 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. During the year ended December 31, 2015, we charged $2.8 million to Tres Palacios and $0.5 million to Jackalope.

(3) Includes $22.4 million, $16.0 million and $10.0 million of net unit-based compensation charges allocated from CEQP to CMLP for the years ended December 31, 2017, 2016 and 2015. In addition, includes $3.0 million, $3.0 million and $0.8 million of CMLP’s general and administrative costs allocated to CEQP during the years ended December 31, 2017, 2016 and 2015.


(4)	Includes $3.1 million, $3.2 million and $0.1 million unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the years ended December 31, 2017, 2016 and 2015.

The following table shows accounts receivable and accounts payable from our affiliates as of December 31, 2017 and 2016 (in millions):



	December 31,
	2017		2016
Accounts receivable at CEQP and CMLP	$	7.1	$	5.6
Accounts payable at CEQP	$	7.4	$	2.5
Accounts payable at CMLP	$	5.0	$	—

Segments

12 Months Ended

Dec. 31, 2017

Segment Reporting [Abstract]

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 loss to EBITDA (in millions):



	Year Ended December 31,
	2017			2016			2015
Net loss	$	(166.6	)	$	(192.1	)	$	(2,303.7	)
Add:
Interest and debt expense, net	99.4			125.1			140.1
(Gain) loss on modification/extinguishment of debt	37.7			(10.0		)	20.0
Provision (benefit) for income taxes	(0.8		)	0.3			(1.4		)
Depreciation, amortization and accretion	191.7			229.6			300.1
EBITDA	$	161.4		$	152.9		$	(1,844.9	)

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



	Year Ended December 31,
	2017			2016			2015
Net loss	$	(175.5	)	$	(197.5	)	$	(1,410.6	)
Add:
Interest and debt expense, net	99.4			125.1			130.5
(Gain) loss on modification/extinguishment of debt	37.7			(10.0		)	18.9
Depreciation, amortization and accretion	202.7			240.5			278.5
EBITDA	$	164.3		$	158.1		$	(982.7	)

The following tables summarize CEQP’s and CMLP’s reportable segment data for the years ended December 31, 2017, 2016 and 2015 (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 (loss) from unconsolidated affiliates below was approximately $32.5 million, $29.6 million and $86.1 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, 2017, 2016 and 2015, respectively.

Crestwood Equity



	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, 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
Other income, net	—			—			—			0.5			0.5
EBITDA	$	243.1		$	77.1		$	(79.6	)	$	(87.7	)	$	152.9
Goodwill	$	45.9		$	—		$	153.1		$	—		$	199.0
Total assets	$	2,359.7		$	1,094.6		$	972.2		$	22.4		$	4,448.9
Purchases of property, plant and equipment	$	76.6		$	3.3		$	19.1		$	1.7		$	100.7



	Year Ended December 31, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	1,381.0		$	266.3		$	985.5		$	—		$	2,632.8
Intersegment revenues	66.7			—			(66.7		)	—			—
Costs of product/services sold	1,103.9			20.1			759.5			—			1,883.5
Operations and maintenance expense	89.0			31.7			69.5			—			190.2
General and administrative expense	—			—			—			116.3			116.3
Loss on long-lived assets	(787.3		)	(1.6		)	(32.3		)	—			(821.2		)
Goodwill impairment	(329.7		)	(623.4		)	(453.2		)	—			(1,406.3		)
Loss from unconsolidated affiliates, net	(43.4		)	(17.4		)	—			—			(60.8		)
Other income, net	—			—			—			0.6			0.6
EBITDA	$	(905.6	)	$	(427.9	)	$	(395.7	)	$	(115.7	)	$	(1,844.9	)
Purchases of property, plant and equipment	$	132.7		$	26.4		$	22.8		$	0.8		$	182.7

Crestwood Midstream



	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
Goodwill	$	45.9		$	—		$	153.1		$	—		$	199.0
Total assets	$	2,561.9		$	1,094.6		$	972.2		$	11.9		$	4,640.6
Purchases of property, plant and equipment	$	76.6		$	3.3		$	19.1		$	1.7		$	100.7



	Year Ended December 31, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	1,381.0		$	266.3		$	985.5		$	—		$	2,632.8
Intersegment revenues	66.7			—			(66.7		)	—			—
Costs of product/services sold	1,103.9			20.1			759.5			—			1,883.5
Operations and maintenance expense	89.0			30.2			69.5			—			188.7
General and administrative expense	—			—			—			105.6			105.6
Loss on long-lived assets, net	(194.1		)	(1.4		)	(32.3		)	—			(227.8		)
Goodwill impairment	(72.5		)	(623.4		)	(453.2		)	—			(1,149.1		)
Loss from unconsolidated affiliates, net	(43.4		)	(17.4		)	—			—			(60.8		)
EBITDA	$	(55.2	)	$	(426.2	)	$	(395.7	)	$	(105.6	)	$	(982.7	)
Purchases of property, plant and equipment	$	132.7		$	26.4		$	22.8		$	0.8		$	182.7

Major Customers

No customer accounted for 10% or more of our total consolidated revenues for the years ended December 31, 2017, 2016 or 2015 at CEQP or CMLP.

Condensed Consolidating Financial Information

12 Months Ended

Dec. 31, 2017

Condensed Financial Information of Parent Company Only 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, 2017, 2016 and 2015. 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, 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 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 partners 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 Balance Sheet
December 31, 2016
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	1.3	$	—	$	—	$	—		$	1.3
Accounts receivable	—		289.3		0.5		—			289.8
Inventory	—		66.0		—		—			66.0
Other current assets	—		16.0		—		—			16.0
Total current assets	1.3		371.3		0.5		—			373.1

Property, plant and equipment, net	—		2,298.4		—		—			2,298.4
Goodwill and intangible assets, net	—		851.9		—		—			851.9
Investments in consolidated affiliates	4,093.7		—		—		(4,093.7		)	—
Investments in unconsolidated affiliates	—		—		1,115.4		—			1,115.4
Other assets	—		1.8		—		—			1.8
Total assets	$	4,095.0	$	3,523.4	$	1,115.9	$	(4,093.7	)	$	4,640.6

Liabilities and partners’ capital
Current liabilities:
Accounts payable	$	—	$	214.5	$	—	$	—		$	214.5
Other current liabilities	23.1		94.4		—		—			117.5
Total current liabilities	23.1		308.9		—		—			332.0

Long-term liabilities:
Long-term debt, less current portion	1,521.2		1.5		—		—			1,522.7
Other long-term liabilities	—		42.0		—		—			42.0
Deferred income taxes	—		0.7		—		—			0.7

Partners’ capital	2,550.7		3,170.3		923.4		(4,093.7		)	2,550.7
Interest of non-controlling partners in subsidiary	—		—		192.5		—			192.5
Total partners’ capital	2,550.7		3,170.3		1,115.9		(4,093.7		)	2,743.2
Total liabilities and partners’ capital	$	4,095.0	$	3,523.4	$	1,115.9	$	(4,093.7	)	$	4,640.6



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
Expenses:
Operations and maintenance	—			136.0			—			—			136.0
General and administrative	67.6			25.5			—			—			93.1
Depreciation, amortization and accretion	—			202.7			—			—			202.7
	67.6			364.2			—			—			431.8
Other operating expenses:
Gain on long-lived assets, net	—			(65.6		)	—			—			(65.6		)
Goodwill impairment	—			(38.8		)	—			—			(38.8		)
Loss on contingent consideration	—			—			(57.0		)	—			(57.0		)
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 partners	—			—			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 LP
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
Expenses:
Operations and maintenance	—			155.0			—		—		155.0
General and administrative	66.4			19.2			—		—		85.6
Depreciation, amortization and accretion	—			240.5			—		—		240.5
	66.4			414.7			—		—		481.1
Other operating expenses:
Loss on long-lived assets, net	—			(65.6		)	—		—		(65.6		)
Goodwill impairment	—			(162.6		)	—		—		(162.6		)
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 partners	—			—			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
Condensed Consolidating Statements of Operations
Year Ended December 31, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations		Consolidated
Revenues	$	—		$	2,632.8		$	—		$	—	$	2,632.8
Costs of product/services sold	—			1,883.5			—			—		1,883.5
Expenses:
Operations and maintenance	—			188.7			—			—		188.7
General and administrative	65.3			40.3			—			—		105.6
Depreciation, amortization and accretion	—			278.5			—			—		278.5
	65.3			507.5			—			—		572.8
Other operating expenses:
Loss on long-lived assets, net	—			(227.8		)	—			—		(227.8		)
Goodwill impairment	—			(1,149.1		)	—			—		(1,149.1		)
Operating loss	(65.3		)	(1,135.1		)	—			—		(1,200.4		)
Loss from unconsolidated affiliates, net	—			—			(60.8		)	—		(60.8		)
Interest and debt expense, net	(130.5		)	—			—			—		(130.5		)
Loss on modification/extinguishment of debt	(18.9		)	—			—			—		(18.9		)
Equity in net income (loss) of subsidiaries	(1,219.0		)	—			—			1,219.0		—
Net income (loss)	(1,433.7		)	(1,135.1		)	(60.8		)	1,219.0		(1,410.6		)
Net income attributable to non-controlling partners	—			—			23.1			—		23.1
Net income (loss) attributable to Crestwood Midstream Partners LP	(1,433.7		)	(1,135.1		)	(83.9		)	1,219.0		(1,433.7		)
Net income attributable to Class A preferred units	23.1			—			—			—		23.1
Net income (loss) attributable to partners	$	(1,456.8	)	$	(1,135.1	)	$	(83.9	)	$	1,219.0	$	(1,456.8	)



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	(6.7		)	(181.7		)	—			—			(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	(2.4		)	43.5			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 debt-related deferred 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	413.4			(413.4		)	—			—			—
Other	—			0.2			—			—			0.2
Net cash provided by (used in) financing activities	164.4			(422.7		)	(47.2		)	4.3			(301.2		)

Net change in cash	(0.3		)	—			—			—			(0.3		)
Cash at beginning of period	1.3			—			—			—			1.3
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	(1.7		)	(99.0		)	—			—			(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 distributions from consolidated affiliates	26.2			—			—			(26.2		)	—
Net cash provided by (used in) investing activities	24.5			866.5			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 debt-related deferred 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	1,365.8			(1,365.8		)	—			—			—
Net cash provided by (used in) financing activities	164.7			(1,369.3		)	(41.4		)	26.2			(1,219.8		)

Net change in cash	1.2			—			—			—			1.2
Cash at beginning of period	0.1			—			—			—			0.1
Cash at end of period	$	1.3		$	—		$	—		$	—		$	1.3



Crestwood Midstream Partners LP
Condensed Consolidating Statements of Cash Flows
Year Ended December 31, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:	$	(190.8	)	$	650.0		$	12.6		$	—		$	471.8

Cash flows from investing activities:
Purchases of property, plant and equipment	(0.8		)	(181.9		)	—			—			(182.7		)
Investment in unconsolidated affiliates	—			—			(41.8		)	—			(41.8		)
Capital distributions from unconsolidated affiliates	—			—			9.3			—			9.3
Net proceeds from sale of assets	—			2.7			—			—			2.7
Capital contributions to consolidated affiliates	(31.2		)	—			—			31.2			—
Net cash provided by (used in) investing activities	(32.0		)	(179.2		)	(32.5		)	31.2			(212.5		)

Cash flows from financing activities:
Proceeds from the issuance of long-term debt	3,490.1			—			—			—			3,490.1
Payments on long-term debt	(2,960.9		)	—			—			—			(2,960.9		)
Payments on capital leases	—			(2.2		)	—			—			(2.2		)
Payments for debt-related deferred costs	(17.3		)	—			—			—			(17.3		)
Financing fees paid for early debt redemption	(13.6		)	—			—			—			(13.6		)
Distributions to partners	(808.2		)	—			(11.3		)	—			(819.5		)
Contributions from parent	—			—			31.2			(31.2		)	—
Net proceeds from issuance of preferred units	58.8			—			—			—			58.8
Taxes paid for unit-based compensation vesting	—			(2.1		)	—			—			(2.1		)
Change in intercompany balances	474.1			(474.1		)	—			—			—
Other	(0.1		)	—			—			—			(0.1		)
Net cash provided by (used in) financing activities	222.9			(478.4		)	19.9			(31.2		)	(266.8		)

Net change in cash	0.1			(7.6		)	—			—			(7.5		)
Cash at beginning of period	—			7.6			—			—			7.6
Cash at end of period	$	0.1		$	—		$	—		$	—		$	0.1

Schedule I - Crestwood Equity Partners LP - Parent Only

12 Months Ended

Dec. 31, 2017

Condensed Financial Information of Parent Company Only 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,
	2017		2016
Assets
Current assets:
Cash	$	0.3	$	0.3
Total current assets	0.3		0.3

Property, plant and equipment, net	1.2		1.4
Intangible assets, net	1.4		4.5
Investments in subsidiaries	2,005.1		2,342.7
Other assets	3.5		4.3
Total assets	$	2,011.5	$	2,353.2

Liabilities and partners’ capital
Current liabilities:
Accounts payable	$	2.7	$	2.7
Accrued expenses	1.2		1.4
Total current liabilities	3.9		4.1

Other long-term liabilities	2.1		2.6

Total partners’ capital	2,005.5		2,346.5
Total liabilities and partners’ capital	$	2,011.5	$	2,353.2

See accompanying notes.

Schedule I

Crestwood Equity Partners LP

Parent Only

Condensed Statements of Operations

(in millions)



	Year Ended December 31,
	2017			2016			2015
Revenues	$	—		$	—		$	—
Expenses	6.7			6.0			14.5
Operating loss	(6.7		)	(6.0		)	(14.5		)
Interest and debt expense, net	—			—			(9.6		)
Equity in net loss of subsidiaries	(160.4		)	(186.6		)	(2,279.1		)
Loss on modification/extinguishment of debt	—			—			(1.1		)
Other income, net	0.5			0.5			0.6
Net loss	(166.6		)	(192.1		)	(2,303.7		)
Net income (loss) attributable to non-controlling partners	25.3			24.2			(636.8		)
Net income loss attributable to Crestwood Equity Partners LP	$	(191.9	)	$	(216.3	)	$	(1,666.9	)

See accompanying notes.

Schedule I

Crestwood Equity Partners LP

Parent Only

Condensed Statements of Comprehensive Income

(in millions)



	Year Ended December 31,
	2017			2016			2015
Net loss	$	(166.6	)	$	(192.1	)	$	(2,303.7	)
Change in fair value of Suburban Propane Partners, LP units	(0.8		)	0.8			(2.7		)
Comprehensive loss	(167.4		)	(191.3		)	(2,306.4		)
Comprehensive income (loss) attributable to non-controlling interest	25.3			24.2			(636.8		)
Comprehensive loss attributable to Crestwood Equity Partners LP	$	(192.7	)	$	(215.5	)	$	(1,669.6	)

See accompanying notes.

Schedule I

Crestwood Equity Partners LP

Parent Only

Condensed Statements of Cash Flows

(in millions)



	Year Ended December 31,
	2017			2016			2015
Cash flows from operating activities	$	(3.6	)	$	(3.5	)	$	(14.7	)

Cash flows from investing activities	174.0			227.6			593.8

Cash flows from financing activities:
Proceeds from the issuance of long-term debt	—			—			771.7
Principal payments on long-term debt	—			(0.2		)	(1,152.1		)
Distributions paid to partners	(182.6		)	(219.8		)	(171.5		)
Proceeds from issuance of common units	15.2			—			—
Change in intercompany balances	(3.0		)	(4.2		)	(30.5		)
Net cash used in financing activities	(170.4		)	(224.2		)	(582.4		)

Net change in cash	—			(0.1		)	(3.3		)
Cash at beginning of period	0.3			0.4			3.7
Cash at end of period	$	0.3		$	0.3		$	0.4

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, 2017, 2016 and 2015, we received cash distributions from Crestwood Midstream Partners LP of approximately $174.0 million, $227.6 million and $31.4 million.

- Definition

The entire disclosure for condensed financial information, including the financial position, cash flows, and the results of operations of the registrant (parent company) as of the same dates or for the same periods for which audited consolidated financial statements are being presented. Alternatively, the details of this disclosure can be reported by the specific parent company taxonomy elements, indicating the appropriate date and period contexts in an instance document.

+ References + Details

Schedule II - Crestwood Equity Parnters LP - Valuation and Qualifying Accounts

12 Months Ended

Dec. 31, 2017

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, 2017, 2016 and 2015

(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
2017	$	1.9	$	1.5	$	—	$	(1.0	)	$	2.4
2016	0.4		1.9		—		(0.4		)	1.9
2015	0.1		—		0.4		(0.1		)	0.4

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

12 Months Ended

Dec. 31, 2017

Accounting Policies [Abstract]

Use of Estimates

Cash

We consider all highly liquid investments with an original maturity of less than three months to be cash.

Inventory

Property, Plant and Equipment



	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.

•


•	During 2015, we incurred a $31.2 million impairment of our property, plant and equipment related to our Watkins Glen development project in our marketing, supply and logistics operations, which resulted from continued delays and uncertainties in the permitting of our proposed NGL storage facility.

Identifiable Intangible Assets

Goodwill

Identifiable Intangible 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.


•	During 2015, Crestwood Equity fully impaired $238.9 million of its intangible assets related to its Barnett gathering and processing operations, which resulted from the actions of our primary customer in the Barnett Shale, Quicksilver, related to filing for protection under Chapter 11 of the U.S. Bankruptcy Code in 2015.

•

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	6 - 8

Investment in Unconsolidated Affiliate

Investment in Unconsolidated Affiliates

Asset Retirement Obligations

Revenue Recognition

We recognize revenues for these services and products when all of the following criteria are met:

• services have been rendered or products delivered or sold;

• persuasive evidence of an exchange arrangement exists;

• the price for services is fixed or determinable; and

• collectability is reasonably assured.

Credit Risk and Concentrations

Income Taxes

Environmental Costs and Other Contingencies

Price Risk Management Activities

We did not have any derivatives identified as fair value hedges or cash flow hedges for accounting purposes during the years ended December 31, 2017, 2016 or 2015.

Unit-Based Compensation

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

12 Months Ended

Dec. 31, 2017

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	6 - 8

Intangible assets consisted of the following at December 31, 2017 and 2016 (in millions):



	CEQP				CMLP
	December 31,				December 31,
	2017		2016		2017		2016
Customer accounts	$	438.9	$	541.9	$	438.9	$	541.9
Covenants not to compete	—		1.0		—		1.0
Gas gathering, compression and processing contracts	325.2		325.2		325.2		325.2
Trademarks	24.7		30.5		9.2		15.0
	788.8		898.6		773.3		883.1
Less: accumulated amortization	191.6		241.2		177.6		230.2
Total intangible assets, net	$	597.2	$	657.4	$	595.7	$	652.9

The following table summarizes total accumulated amortization of our intangible assets at December 31, 2017 and 2016 (in millions):



	CEQP				CMLP
	December 31,				December 31,
	2017		2016		2017		2016
Customer accounts	$	89.8	$	162.4	$	89.8	$	162.4
Gas gathering, compression and processing contracts	82.0		63.2		82.0		63.2
Trademarks	19.8		15.6		5.8		4.6
Total accumulated amortization	$	191.6	$	241.2	$	177.6	$	230.2

Schedule of Goodwill

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



	Goodwill Impairments during the Year Ended December 31, 2015		Goodwill at January 1, 2016		Goodwill Impairments during the Year Ended December 31, 2016		Other				Goodwill at December 31, 2016		Impact of Sale of US Salt				Goodwill Impairments during the Year Ended December 31, 2017		Goodwill at December 31, 2017
G&P
Fayetteville	$	72.5	$	—	$	—	$	—			$	—	$	—			$	—	$	—
Marcellus	—		8.6		8.6		—				—		—				—		—
Arrow	—		45.9		—		—				45.9		—				—		45.9
S&T
Northeast Storage and Transportation	—		726.3		—		(726.3		)	⁽¹⁾	—		—				—		—
COLT	623.4		44.9		44.9		—				—		—				—		—
MS&L																			—
West Coast	85.9		—		—		2.4			⁽²⁾	2.4		—				2.4		—
Supply and Logistics	99.0		167.2		65.5		—				101.7		—				—		101.7
Storage and Terminals	53.7		50.5		14.1		—				36.4		—				36.4		—
US Salt	—		12.6		—		—				12.6		(12.6		)	⁽³⁾	—		—
Trucking	148.4		29.5		29.5		—				—		—				—		—
Watkins Glen	66.2		—		—		—				—		—				—		—
Total CMLP	$	1,149.1	$	1,085.5	$	162.6	$	(723.9	)		$	199.0	$	(12.6	)		$	38.8	$	147.6
Barnett (G&P)	257.2		—		—		—				—		—				—		—
Total CEQP	$	1,406.3	$	1,085.5	$	162.6	$	(723.9	)		$	199.0	$	(12.6	)		$	38.8	$	147.6


(1)	Reflects impact of the deconsolidation of our NE S&T assets in June 2016.


(2)	In December 2016, we acquired four NGL terminals for our MS&L segment for approximately $7.2 million with total goodwill of approximately $2.4 million. This acquisition was not material to our consolidated financial statements as of and for the year ended December 31, 2016.

(3) In December 2017, we sold 100% of our equity interests in US Salt to an affiliate of Kissner Group Holdings LP.

Certain Balance Sheet Information (Tables)

12 Months Ended

Dec. 31, 2017

Balance Sheet Related Disclosures [Abstract]

Property, Plant And Equipment

Property, plant and equipment of the following at December 31, 2017 and 2016 (in millions):



	CEQP				CMLP
	December 31,				December 31,
	2017		2016		2017		2016
Gathering systems and pipelines and related assets	$	678.0	$	639.4	$	820.9	$	782.3
Facilities and equipment	1,141.4		1,328.3		1,326.5		1,513.4
Buildings, land, rights-of-way, storage rights and easements	319.1		315.4		322.8		319.1
Vehicles	37.3		45.7		35.5		44.0
Construction in process	87.5		85.9		87.5		85.9
Salt deposits	—		120.5		—		120.5
Office furniture and fixtures	21.9		20.2		22.1		20.3
	2,285.2		2,555.4		2,615.3		2,885.5
Less: accumulated depreciation and depletion	464.4		457.8		607.8		587.1
Total property, plant and equipment, net	$	1,820.8	$	2,097.6	$	2,007.5	$	2,298.4

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	6 - 8

Intangible assets consisted of the following at December 31, 2017 and 2016 (in millions):



	CEQP				CMLP
	December 31,				December 31,
	2017		2016		2017		2016
Customer accounts	$	438.9	$	541.9	$	438.9	$	541.9
Covenants not to compete	—		1.0		—		1.0
Gas gathering, compression and processing contracts	325.2		325.2		325.2		325.2
Trademarks	24.7		30.5		9.2		15.0
	788.8		898.6		773.3		883.1
Less: accumulated amortization	191.6		241.2		177.6		230.2
Total intangible assets, net	$	597.2	$	657.4	$	595.7	$	652.9

The following table summarizes total accumulated amortization of our intangible assets at December 31, 2017 and 2016 (in millions):



	CEQP				CMLP
	December 31,				December 31,
	2017		2016		2017		2016
Customer accounts	$	89.8	$	162.4	$	89.8	$	162.4
Gas gathering, compression and processing contracts	82.0		63.2		82.0		63.2
Trademarks	19.8		15.6		5.8		4.6
Total accumulated amortization	$	191.6	$	241.2	$	177.6	$	230.2

Schedule of Intangible Assets, Future Amortization Expense

Estimated amortization of our intangible assets for the next five years is as follows (in millions):



	CEQP		CMLP
Year Ending December 31,
2018	$	43.4	$	42.0
2019	41.7		41.7
2020	41.7		41.7
2021	41.7		41.7
2022	41.7		41.7

Schedule of Accrued Liabilities

Accrued expenses and other liabilities consisted of the following at December 31, 2017 and 2016 (in millions):



	CEQP				CMLP
	December 31,				December 31,
	2017		2016		2017		2016
Accrued expenses	$	56.6	$	46.5	$	55.5	$	45.1
Accrued property taxes	4.8		4.2		4.8		4.2
Accrued natural gas purchases	—		4.9		—		4.9
Income tax payable	0.3		1.6		0.3		0.4
Interest payable	20.3		22.8		20.3		22.8
Accrued additions to property, plant and equipment	22.3		1.7		22.2		1.7
Capital leases	1.0		1.3		1.0		1.3
Deferred revenue	0.6		7.5		0.6		7.5
Total accrued expenses and other liabilities	$	105.9	$	90.5	$	104.7	$	87.9

Asset Retirement Obligations (Tables)

12 Months Ended

Dec. 31, 2017

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, 2017 and 2016 (in millions):



	December 31,
	2017			2016
Net asset retirement obligation at January 1	$	27.8		$	26.4
Liabilities incurred	—			1.0
Liabilities settled	(1.2		)	(1.2		)
Accretion expense	1.4			1.6
Change in estimate	(0.5		)	—
Net asset retirement obligation at December 31	$	27.5		$	27.8

Investments in Unconsolidated Affiliates Investments in Unconsolidated Affiliates (Tables)

12 Months Ended

Dec. 31, 2017

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments [Table Text Block]

Distributions and Contributions



	Distributions						Contributions
	Year Ended December 31,						Year Ended December 31,
	2017		2016		2015		2017		2016		2015
Stagecoach Gas	$	47.3	$	16.0	$	—	$	0.8	$	—	$	—
Jackalope⁽¹⁾	26.3		27.4		12.5		3.5		1.4		25.4
Tres Holdings⁽²⁾	9.0		8.5		7.4		5.6		11.0		5.7
PRBIC⁽¹⁾	1.6		2.0		1.9		—		—		10.7
Crestwood Permian⁽³⁾	23.4		—		—		117.5		—		—
Total	$	107.6	$	53.9	$	21.8	$	127.4	$	12.4	$	41.8

(1) Jackalope and PRBIC are required to make quarterly distributions of its available cash to its members based on their respective ownership percentage. We

received a cash distribution of $7.4 million from Jackalope in January 2018, and we received a cash distribution of $0.3 million from PRBIC in February

2018.

(2) 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.

(3) 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.

Operating Results Data



	Year Ended December 31,
	2017						2016						2015
	Operating Revenues		Operating Expenses		Net Income		Operating Revenues		Operating Expenses		Net Income		Operating Revenues		Operating Expenses		Net Income
Stagecoach	$	168.6	$	77.7	$	91.1	$	99.3	$	44.1	$	55.3	$	—	$	—	$	—
Other⁽¹⁾	181.8		143.6		38.9		127.6		113.9		13.5		104.7		79.5		24.9
Total	$	350.4	$	221.3	$	130.0	$	226.9	$	158.0	$	68.8	$	104.7	$	79.5	$	24.9

(1)

Financial Position Data



	December 31,
	2017										2016
	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⁾	$	55.1	$	1,765.4	$	7.0	$	1.4	$	1,812.1	$	57.0	$	1,807.6	$	6.0	$	4.1	$	1,854.5
Other⁽²⁾⁽³⁾	81.3		801.1		53.4		93.6		735.4		50.4		708.5		23.2		74.4		661.3
Total	$	136.4	$	2,566.5	$	60.4	$	95.0	$	2,547.5	$	107.4	$	2,516.1	$	29.2	$	78.5	$	2,515.8


(1)	As of December 31, 2017, our equity in the underlying net assets of Stagecoach Gas exceeded our investment balance by approximately $51.4 million. This excess amount is entirely attributable to goodwill and, as such, is not subject to amortization. Our Stagecoach Gas investment is included in our storage and transportation segment.

(2)

(3)

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,
	2017			2017		2016			2017		2016				2015
Stagecoach Gas Services LLC	50.00	%		$	849.8	$	871.0		$	25.3	$	15.9			$	—
Jackalope Gas Gathering Services, L.L.C.	50.00	%	⁽¹⁾	184.9		197.2			10.5		20.8				(43.4		)	⁽³⁾
Crestwood Permian Basin Holdings LLC	50.00	%		102.0		(0.5		)	8.4		(0.5		)		—
Tres Palacios Holdings LLC	50.01	%		37.8		39.0			2.2		(0.3		)		2.5
Powder River Basin Industrial Complex, LLC⁽²⁾	50.01	%		8.5		8.7			1.4		(4.4		)	⁽³⁾	(19.9		)	⁽³⁾
Total				$	1,183.0	$	1,115.4		$	47.8	$	31.5			$	(60.8	)


(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)	During the year ended December 31, 2015, we recorded additional equity earnings of approximately $3.2 million related to a gain associated with the adjustment of our member’s capital account by our equity investee.

(3)

Risk Management (Tables)

12 Months Ended

Dec. 31, 2017

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

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, 2017		December 31, 2016
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, crude and heating oil (MMBbls)	15.3	17.5	13.1	15.1
Natural gas (MMcf)	780	660	—	—

Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2017

Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]

Schedule of Carrying Values and Estimated Fair Values of Debt Instruments

The following table reflects the carrying value (reduced for deferred financing costs associated with the respective notes) and fair value of our senior notes (in millions):



	December 31, 2017				December 31, 2016
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
2020 Senior Notes	$	—	$	—	$	340.6	$	350.2
2022 Senior Notes	$	—	$	—	$	429.3	$	447.3
2023 Senior Notes	$	692.1	$	728.8	$	690.6	$	722.6
2025 Senior Notes	$	492.3	$	517.9	$	—	$	—

Assets And Liabilities Measured At Fair Value On Recurring Basis



	December 31, 2017
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting⁽¹⁾			Collateral/Margin Received or Paid			Recorded in Balance Sheet
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

	December 31, 2016
	Level 1		Level 2		Level 3		Gross Fair Value		Contract Netting⁽¹⁾			Collateral/Margin Received or Paid			Recorded in Balance Sheet
Assets
Assets from price risk management	$	0.6	$	84.4	$	—	$	85.0	$	(67.8	)	$	(10.9	)	$	6.3
Suburban Propane Partners, L.P. units⁽²⁾	4.3		—		—		4.3		—			—			4.3
Total assets at fair value	$	4.9	$	84.4	$	—	$	89.3	$	(67.8	)	$	(10.9	)	$	10.6

Liabilities
Liabilities from price risk management	$	2.7	$	90.2	$	—	$	92.9	$	(67.8	)	$	3.5		$	28.6
Total liabilities at fair value	$	2.7	$	90.2	$	—	$	92.9	$	(67.8	)	$	3.5		$	28.6


(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)

12 Months Ended

Dec. 31, 2017

Text Block [Abstract]

Components Of Long-Term Debt

Long-term debt consisted of the following at December 31, 2017 and 2016, (in millions):



	December 31,
	2017		2016
Credit Facility	$	318.2	$	77.0
2020 Senior Notes	—		338.8
Fair value adjustment of 2020 Senior Notes	—		1.8
2022 Senior Notes	—		436.4
2023 Senior Notes	700.0		700.0
2025 Senior Notes	500.0		—
Other	2.4		3.7
Less: deferred financing costs, net	28.4		34.0
Total debt	1,492.2		1,523.7
Less: current portion	0.9		1.0
Total long-term debt, less current portion	$	1,491.3	$	1,522.7

Schedule of Maturities of Long-term Debt



2018	$	0.9
2019	0.9
2020	318.4
2021	0.2
2022	0.2
Thereafter	1,200.0
Total debt	$	1,520.6

- Definition

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=84159872&loc=d3e21475-112644

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 470
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=75038535&loc=d3e64711-112823

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(e),(f))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=64930739&loc=d3e28878-108400

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=84159872&loc=d3e21538-112644

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=84159872&loc=d3e21506-112644

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=64930785&loc=d3e28541-108399

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=64930785&loc=d3e28551-108399

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=84159872&loc=d3e21521-112644

+ Details

Income Taxes (Tables)

12 Months Ended

Dec. 31, 2017

Income Tax Disclosure [Abstract]

Schedule of Components of Income Tax Expense (Benefit)

The (provision) benefit for income taxes for the years ended December 31, 2017, 2016, and 2015 consisted of the following (in millions):



	CEQP									CMLP
	Year Ended December 31,									Year Ended December 31,
	2017			2016			2015			2017⁽¹⁾		2016			2015
Current:
Federal	$	(1.1	)	$	(3.2	)	$	(1.6	)	$	—	$	—		$	—
State	(0.2		)	(0.2		)	(0.6		)	—		0.2			(0.3		)
Total current	(1.3		)	(3.4		)	(2.2		)	—		0.2			(0.3		)
Deferred:
Federal	2.1			3.0			2.9			—		—			—
State	—			0.1			0.7			—		(0.2		)	0.3
Total deferred	2.1			3.1			3.6			—		(0.2		)	0.3
(Provision) benefit for income taxes	$	0.8		$	(0.3	)	$	1.4		$	—	$	—		$	—


(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, 2017 and 2016 are as follows (in millions).



	CEQP						CMLP
	December 31,						December 31,
	2017			2016			2017			2016
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 acquired company	(3.5		)	(5.5		)	(0.7		)	(0.7		)
Total deferred tax liability	(3.5		)	(5.5		)	(0.7		)	(0.7		)
Net deferred tax liability	$	(3.3	)	$	(5.3	)	$	(0.7	)	$	(0.7	)

Partners' Capital (Tables)

12 Months Ended

Dec. 31, 2017

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, 2017, 2016 and 2015 is presented below:



Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
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
2015
February 6, 2015	February 13, 2015	$	1.375	$	25.8
May 8, 2015	May 15, 2015	$	1.375	25.7
August 7, 2015	August 14, 2015	$	1.375	25.7
November 6, 2015	November 13, 2015	$	1.375	94.3
				$	171.5

Schedule of Limited Partners' Capital Account by Class

The components of net income (loss) attributable to non-controlling partners for the years ended December 31, 2017, 2016 and 2015 are as follows (in millions):



	Year Ended December 31,
	2017		2016		2015
Crestwood Niobrara preferred interests	$	25.3	$	24.2	$	23.1
CMLP net income attributable to non-controlling partners	25.3		24.2		23.1
Crestwood Midstream limited partner interests	—		—		(683.0		)
Crestwood Midstream Class A preferred units	—		—		23.1
CEQP net income (loss) attributable to non-controlling partners	$	25.3	$	24.2	$	(636.8	)

CMLP

Distribution Made to Limited Liability Company (LLC) Member [Line Items]

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



Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2015
February 6, 2015	February 13, 2015	$	0.41	$	74.3
May 8, 2015	May 15, 2015	$	0.41	74.3
August 7, 2015	August 14, 2015	$	0.41	74.3
				$	222.9

Partners' Capital Schedule of Issuance of Units (Tables)

12 Months Ended

Dec. 31, 2017

Schedule of Issuance of Units [Abstract]

Schedule Of Issuances And Net Proceeds Of Common Units [Table Text Block]

The table below shows the units issued and the net proceeds from the issuances:



Issuance Dates	Common Units	Net Proceeds⁽¹⁾ (in millions)
Third Quarter 2017	437,518	$	10.6
Fourth Quarter 2017	195,753	4.6
Total 2017	633,271	$	15.2

Equity Plans (Tables)

12 Months Ended

Dec. 31, 2017

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, 2017, 2016 and 2015.



	Units		Weighted-Average Grant Date Fair Value
Unvested - January 1, 2015	131,588		$	132.10
Vested - restricted units	(91,798	)	$	121.13
Vested - phantom units	(4,856	)	$	67.10
Granted - restricted units	142,255		$	55.25
Granted - phantom units	42,349		$	62.31
Modification - restricted units	226,401		$	68.85
Modification - phantom units	41,269		$	58.36
Forfeited ⁽¹⁾	(20,994	)	$	89.97
Unvested - December 31, 2015	466,214		$	69.80
Vested - restricted units	(193,295	)	$	76.82
Granted - restricted units	1,067,535		$	14.58
Granted - phantom units	17,467		$	15.54
Forfeited	(65,591	)	$	25.13
Unvested - December 31, 2016	1,292,330		$	24.67
Vested - restricted units	(607,115	)	$	28.00
Vested - performance units	(31,106	)	$	30.27
Granted - restricted units	919,411		$	25.69
Granted - phantom units	15,849		$	25.02
Granted - performance units	405,620		$	30.21
Forfeited - restricted units	(140,137	)	$	23.73
Forfeited - performance units	(24,756	)	$	30.45
Unvested - December 31, 2017	1,830,096		$	25.21


(1)	We implemented a company-wide initiative to reduce operating costs in 2015 and beyond, which included a reduction in workforce. As a result, 7,263 restricted units were forfeited during the year ended December 31, 2015.

Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2017

Commitments and Contingencies Disclosure [Abstract]

Schedule of Future Minimum Rental Payments for Operating Leases

Future minimum lease payments under our noncancelable operating leases for the next five years ending December 31 and in total thereafter consist of the following (in millions):



Year Ending December 31,
2018	$	35.2
2019	30.1
2020	23.2
2021	11.5
2022	7.7
Thereafter	18.8
Total minimum lease payments	$	126.5

Related Party Transactions (Tables)

12 Months Ended

Dec. 31, 2017

Schedule of Related Party Transactions



	Year Ended December 31,
	2017			2016			2015
Gathering and processing revenues at CEQP and CMLP	$	1.8		$	2.6		$	3.9
Gathering and processing costs of product sold at CEQP and CMLP⁽¹⁾	$	15.3		$	17.7		$	28.9
Operations and maintenance expenses charged at CEQP and CMLP⁽²⁾	$	22.3		$	8.1		$	3.3
General and administrative expenses charged by CEQP to CMLP, net⁽³⁾	$	19.4		$	13.0		$	49.5
General and administrative expenses at CEQP charged to (from) Crestwood Holdings, net⁽⁴⁾	$	(1.7	)	$	(2.2	)	$	0.4

(1) Represents natural gas purchases from Sabine Oil and Gas, an affiliate of Crestwood Holdings.

(2)


(4)	Includes $3.1 million, $3.2 million and $0.1 million unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the years ended December 31, 2017, 2016 and 2015.

The following table shows accounts receivable and accounts payable from our affiliates as of December 31, 2017 and 2016 (in millions):



	December 31,
	2017		2016
Accounts receivable at CEQP and CMLP	$	7.1	$	5.6
Accounts payable at CEQP	$	7.4	$	2.5
Accounts payable at CMLP	$	5.0	$	—

Segments (Tables)

12 Months Ended

Dec. 31, 2017

Segment Reporting Information [Line Items]

Reportable Segments

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



	Year Ended December 31,
	2017			2016			2015
Net loss	$	(166.6	)	$	(192.1	)	$	(2,303.7	)
Add:
Interest and debt expense, net	99.4			125.1			140.1
(Gain) loss on modification/extinguishment of debt	37.7			(10.0		)	20.0
Provision (benefit) for income taxes	(0.8		)	0.3			(1.4		)
Depreciation, amortization and accretion	191.7			229.6			300.1
EBITDA	$	161.4		$	152.9		$	(1,844.9	)

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



	Year Ended December 31,
	2017			2016			2015
Net loss	$	(175.5	)	$	(197.5	)	$	(1,410.6	)
Add:
Interest and debt expense, net	99.4			125.1			130.5
(Gain) loss on modification/extinguishment of debt	37.7			(10.0		)	18.9
Depreciation, amortization and accretion	202.7			240.5			278.5
EBITDA	$	164.3		$	158.1		$	(982.7	)

Crestwood Equity



	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, 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
Other income, net	—			—			—			0.5			0.5
EBITDA	$	243.1		$	77.1		$	(79.6	)	$	(87.7	)	$	152.9
Goodwill	$	45.9		$	—		$	153.1		$	—		$	199.0
Total assets	$	2,359.7		$	1,094.6		$	972.2		$	22.4		$	4,448.9
Purchases of property, plant and equipment	$	76.6		$	3.3		$	19.1		$	1.7		$	100.7



	Year Ended December 31, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	1,381.0		$	266.3		$	985.5		$	—		$	2,632.8
Intersegment revenues	66.7			—			(66.7		)	—			—
Costs of product/services sold	1,103.9			20.1			759.5			—			1,883.5
Operations and maintenance expense	89.0			31.7			69.5			—			190.2
General and administrative expense	—			—			—			116.3			116.3
Loss on long-lived assets	(787.3		)	(1.6		)	(32.3		)	—			(821.2		)
Goodwill impairment	(329.7		)	(623.4		)	(453.2		)	—			(1,406.3		)
Loss from unconsolidated affiliates, net	(43.4		)	(17.4		)	—			—			(60.8		)
Other income, net	—			—			—			0.6			0.6
EBITDA	$	(905.6	)	$	(427.9	)	$	(395.7	)	$	(115.7	)	$	(1,844.9	)
Purchases of property, plant and equipment	$	132.7		$	26.4		$	22.8		$	0.8		$	182.7

CMLP

Segment Reporting Information [Line Items]

Reportable Segments

Crestwood Midstream



	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
Goodwill	$	45.9		$	—		$	153.1		$	—		$	199.0
Total assets	$	2,561.9		$	1,094.6		$	972.2		$	11.9		$	4,640.6
Purchases of property, plant and equipment	$	76.6		$	3.3		$	19.1		$	1.7		$	100.7



	Year Ended December 31, 2015
	Gathering and Processing			Storage and Transportation			Marketing, Supply and Logistics			Corporate			Total
Revenues	$	1,381.0		$	266.3		$	985.5		$	—		$	2,632.8
Intersegment revenues	66.7			—			(66.7		)	—			—
Costs of product/services sold	1,103.9			20.1			759.5			—			1,883.5
Operations and maintenance expense	89.0			30.2			69.5			—			188.7
General and administrative expense	—			—			—			105.6			105.6
Loss on long-lived assets, net	(194.1		)	(1.4		)	(32.3		)	—			(227.8		)
Goodwill impairment	(72.5		)	(623.4		)	(453.2		)	—			(1,149.1		)
Loss from unconsolidated affiliates, net	(43.4		)	(17.4		)	—			—			(60.8		)
EBITDA	$	(55.2	)	$	(426.2	)	$	(395.7	)	$	(105.6	)	$	(982.7	)
Purchases of property, plant and equipment	$	132.7		$	26.4		$	22.8		$	0.8		$	182.7

Condensed Consolidating Financial Information (Tables)

12 Months Ended

Dec. 31, 2017

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Condensed Consolidating Balance Sheet



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 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 partners 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 Balance Sheet
December 31, 2016
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	1.3	$	—	$	—	$	—		$	1.3
Accounts receivable	—		289.3		0.5		—			289.8
Inventory	—		66.0		—		—			66.0
Other current assets	—		16.0		—		—			16.0
Total current assets	1.3		371.3		0.5		—			373.1

Property, plant and equipment, net	—		2,298.4		—		—			2,298.4
Goodwill and intangible assets, net	—		851.9		—		—			851.9
Investments in consolidated affiliates	4,093.7		—		—		(4,093.7		)	—
Investments in unconsolidated affiliates	—		—		1,115.4		—			1,115.4
Other assets	—		1.8		—		—			1.8
Total assets	$	4,095.0	$	3,523.4	$	1,115.9	$	(4,093.7	)	$	4,640.6

Liabilities and partners’ capital
Current liabilities:
Accounts payable	$	—	$	214.5	$	—	$	—		$	214.5
Other current liabilities	23.1		94.4		—		—			117.5
Total current liabilities	23.1		308.9		—		—			332.0

Long-term liabilities:
Long-term debt, less current portion	1,521.2		1.5		—		—			1,522.7
Other long-term liabilities	—		42.0		—		—			42.0
Deferred income taxes	—		0.7		—		—			0.7

Partners’ capital	2,550.7		3,170.3		923.4		(4,093.7		)	2,550.7
Interest of non-controlling partners in subsidiary	—		—		192.5		—			192.5
Total partners’ capital	2,550.7		3,170.3		1,115.9		(4,093.7		)	2,743.2
Total liabilities and partners’ capital	$	4,095.0	$	3,523.4	$	1,115.9	$	(4,093.7	)	$	4,640.6

Condensed Consolidating Statements of Operations



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
Expenses:
Operations and maintenance	—			136.0			—			—			136.0
General and administrative	67.6			25.5			—			—			93.1
Depreciation, amortization and accretion	—			202.7			—			—			202.7
	67.6			364.2			—			—			431.8
Other operating expenses:
Gain on long-lived assets, net	—			(65.6		)	—			—			(65.6		)
Goodwill impairment	—			(38.8		)	—			—			(38.8		)
Loss on contingent consideration	—			—			(57.0		)	—			(57.0		)
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 partners	—			—			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 LP
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
Expenses:
Operations and maintenance	—			155.0			—		—		155.0
General and administrative	66.4			19.2			—		—		85.6
Depreciation, amortization and accretion	—			240.5			—		—		240.5
	66.4			414.7			—		—		481.1
Other operating expenses:
Loss on long-lived assets, net	—			(65.6		)	—		—		(65.6		)
Goodwill impairment	—			(162.6		)	—		—		(162.6		)
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 partners	—			—			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
Condensed Consolidating Statements of Operations
Year Ended December 31, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations		Consolidated
Revenues	$	—		$	2,632.8		$	—		$	—	$	2,632.8
Costs of product/services sold	—			1,883.5			—			—		1,883.5
Expenses:
Operations and maintenance	—			188.7			—			—		188.7
General and administrative	65.3			40.3			—			—		105.6
Depreciation, amortization and accretion	—			278.5			—			—		278.5
	65.3			507.5			—			—		572.8
Other operating expenses:
Loss on long-lived assets, net	—			(227.8		)	—			—		(227.8		)
Goodwill impairment	—			(1,149.1		)	—			—		(1,149.1		)
Operating loss	(65.3		)	(1,135.1		)	—			—		(1,200.4		)
Loss from unconsolidated affiliates, net	—			—			(60.8		)	—		(60.8		)
Interest and debt expense, net	(130.5		)	—			—			—		(130.5		)
Loss on modification/extinguishment of debt	(18.9		)	—			—			—		(18.9		)
Equity in net income (loss) of subsidiaries	(1,219.0		)	—			—			1,219.0		—
Net income (loss)	(1,433.7		)	(1,135.1		)	(60.8		)	1,219.0		(1,410.6		)
Net income attributable to non-controlling partners	—			—			23.1			—		23.1
Net income (loss) attributable to Crestwood Midstream Partners LP	(1,433.7		)	(1,135.1		)	(83.9		)	1,219.0		(1,433.7		)
Net income attributable to Class A preferred units	23.1			—			—			—		23.1
Net income (loss) attributable to partners	$	(1,456.8	)	$	(1,135.1	)	$	(83.9	)	$	1,219.0	$	(1,456.8	)

Condensed Consolidating Statements of Cash Flows



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	(6.7		)	(181.7		)	—			—			(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	(2.4		)	43.5			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 debt-related deferred 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	413.4			(413.4		)	—			—			—
Other	—			0.2			—			—			0.2
Net cash provided by (used in) financing activities	164.4			(422.7		)	(47.2		)	4.3			(301.2		)

Net change in cash	(0.3		)	—			—			—			(0.3		)
Cash at beginning of period	1.3			—			—			—			1.3
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	(1.7		)	(99.0		)	—			—			(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 distributions from consolidated affiliates	26.2			—			—			(26.2		)	—
Net cash provided by (used in) investing activities	24.5			866.5			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 debt-related deferred 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	1,365.8			(1,365.8		)	—			—			—
Net cash provided by (used in) financing activities	164.7			(1,369.3		)	(41.4		)	26.2			(1,219.8		)

Net change in cash	1.2			—			—			—			1.2
Cash at beginning of period	0.1			—			—			—			0.1
Cash at end of period	$	1.3		$	—		$	—		$	—		$	1.3



Crestwood Midstream Partners LP
Condensed Consolidating Statements of Cash Flows
Year Ended December 31, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:	$	(190.8	)	$	650.0		$	12.6		$	—		$	471.8

Cash flows from investing activities:
Purchases of property, plant and equipment	(0.8		)	(181.9		)	—			—			(182.7		)
Investment in unconsolidated affiliates	—			—			(41.8		)	—			(41.8		)
Capital distributions from unconsolidated affiliates	—			—			9.3			—			9.3
Net proceeds from sale of assets	—			2.7			—			—			2.7
Capital contributions to consolidated affiliates	(31.2		)	—			—			31.2			—
Net cash provided by (used in) investing activities	(32.0		)	(179.2		)	(32.5		)	31.2			(212.5		)

Cash flows from financing activities:
Proceeds from the issuance of long-term debt	3,490.1			—			—			—			3,490.1
Payments on long-term debt	(2,960.9		)	—			—			—			(2,960.9		)
Payments on capital leases	—			(2.2		)	—			—			(2.2		)
Payments for debt-related deferred costs	(17.3		)	—			—			—			(17.3		)
Financing fees paid for early debt redemption	(13.6		)	—			—			—			(13.6		)
Distributions to partners	(808.2		)	—			(11.3		)	—			(819.5		)
Contributions from parent	—			—			31.2			(31.2		)	—
Net proceeds from issuance of preferred units	58.8			—			—			—			58.8
Taxes paid for unit-based compensation vesting	—			(2.1		)	—			—			(2.1		)
Change in intercompany balances	474.1			(474.1		)	—			—			—
Other	(0.1		)	—			—			—			(0.1		)
Net cash provided by (used in) financing activities	222.9			(478.4		)	19.9			(31.2		)	(266.8		)

Net change in cash	0.1			(7.6		)	—			—			(7.5		)
Cash at beginning of period	—			7.6			—			—			7.6
Cash at end of period	$	0.1		$	—		$	—		$	—		$	0.1

Organization and Description of Business (Narrative) (Detail) - 12 months ended Dec. 31, 2017	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 [Member]
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 Summary of Significant Accounting Policies (Narrative) (Details) - USD ($) $ in Millions				12 Months Ended
	Jan. 01, 2018	Jun. 21, 2017	Jun. 03, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Summary Of Significant Accounting Policies [Line Items]
Assets Held-for-sale, Not Part of Disposal Group				$ 3.0
Loss on long-lived assets, net				(65.6)	$ (65.6)	$ (821.2)
Inventory				68.4	66.0
Estimated Cost to Build				180.0
Contribution of Property		$ 69.0
Net proceeds from sale of assets				225.2	972.7	$ 2.7
Debt Issuance Costs, Net				28.4	34.0
Property, plant and equipment				2,285.2	2,555.4
Deferred revenue				$ 0.6	$ 7.5
Percentage of gross income from qualifying sources required to be subject to federal income tax, minimum				90.00%
Discount rate				12.00%	19.00%	15.00%
Increase (Decrease) in Intangible Assets, Current					$ 8.5
Goodwill impairment				$ 38.8	162.6	$ 1,406.3
Increase (Decrease) in Other Current Assets and Liabilities, Net					11.2
West Coast
Summary Of Significant Accounting Policies [Line Items]
Goodwill, Acquired During Period				2.4
Impaired assets to be disposed of				81.4
Fair value disclosure				66.4
Impairment of intangible assets				0.8
Goodwill impairment				2.4	0.0	85.9
Granite Wash
Summary Of Significant Accounting Policies [Line Items]
Impaired assets to be disposed of						8.5
Barnett
Summary Of Significant Accounting Policies [Line Items]
Impaired assets to be disposed of						354.4
Impairment of intangible assets						238.9
Goodwill impairment				0.0	0.0	257.2
Fayetteville
Summary Of Significant Accounting Policies [Line Items]
Impaired assets to be disposed of						61.9
Impairment of intangible assets						70.9
Goodwill impairment				0.0	0.0	72.5
Haynesville
Summary Of Significant Accounting Policies [Line Items]
Impaired assets to be disposed of						45.7
Impairment of intangible assets						6.0
Marcellus
Summary Of Significant Accounting Policies [Line Items]
Loss on long-lived assets, net				2.5
Goodwill impairment				0.0	8.6	0.0
Watkins Glen
Summary Of Significant Accounting Policies [Line Items]
Impaired assets to be disposed of						31.2
Trucking
Summary Of Significant Accounting Policies [Line Items]
Impairment of intangible assets					31.4
Goodwill impairment				0.0	29.5	148.4
Natural Gas Liquids
Summary Of Significant Accounting Policies [Line Items]
Inventory				67.9	56.7
CMLP
Summary Of Significant Accounting Policies [Line Items]
Loss on long-lived assets, net				(65.6)	(65.6)	(227.8)
Inventory				68.4	66.0
Net proceeds from sale of assets				225.2	972.7	2.7
Property, plant and equipment				2,615.3	2,885.5
Deferred revenue				0.6	7.5
Goodwill impairment				38.8	162.6	1,149.1
Goodwill, Impaired, Accumulated Impairment Loss				1,399.3
Crestwood Equity Partners LP
Summary Of Significant Accounting Policies [Line Items]
Property, plant and equipment				2,285.2	2,555.4
Goodwill impairment				38.8	$ 162.6	1,406.3
Goodwill, Impaired, Accumulated Impairment Loss				$ 1,656.5
Jackalope Gas Gathering Services, LLC
Summary Of Significant Accounting Policies [Line Items]
Equity method investment, other than temporary impairment						51.4
Powder River Basin Industrial Complex, LLC
Summary Of Significant Accounting Policies [Line Items]
Equity method investment, other than temporary impairment						$ 23.4
Minimum
Summary Of Significant Accounting Policies [Line Items]
Discount rate				10.00%	10.00%	9.00%
Maximum
Summary Of Significant Accounting Policies [Line Items]
Discount rate				12.00%	19.00%	12.00%
Equity Method Investments [Member]
Summary Of Significant Accounting Policies [Line Items]
Discount rate						15.50%
Stagecoach Gas Services LLC
Summary Of Significant Accounting Policies [Line Items]
Net proceeds from sale of assets					$ 3.0
Equity method ownership percentage				50.00%
Property, Plant and Equipment, Gross, Period Increase (Decrease)					(1,127.6)
Stagecoach Gas Services LLC \| CEGP
Summary Of Significant Accounting Policies [Line Items]
Net proceeds from sale of assets			$ 975.0		$ 975.0
Stagecoach Gas Services LLC \| CMLP
Summary Of Significant Accounting Policies [Line Items]
Equity method ownership percentage			50.00%		50.00%
Subsequent Event
Summary Of Significant Accounting Policies [Line Items]
New Accounting Pronouncement Change in Balance Sheet Classification	$ 69.1
New Accounting Pronouncement or Change in Accounting Principle, Effect of Adoption, Quantification	$ 20.0

Basis of Presentation and Summary of Significant Accounting Policies (Estimated Useful Lives Of Property, Plant And Equipment) (Detail)	12 Months Ended
	Dec. 31, 2017
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 Summary of Significant Accounting Policies (Estimated Economic Lives Of Intangible Assets) (Detail)	12 Months Ended
	Dec. 31, 2017
Customer Relationships
Finite-Lived Intangible Assets [Line Items]
Weighted-Average Life (years)	20 years
Minimum \| Trademarks
Finite-Lived Intangible Assets [Line Items]
Weighted-Average Life (years)	6 years
Maximum \| Trademarks
Finite-Lived Intangible Assets [Line Items]
Weighted-Average Life (years)	8 years

Basis of Presentation and Summary of Significant Accounting Policies (Goodwill, by Reporting Unit) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Goodwill [Roll Forward]
Beginning Balance		$ 199.0
Goodwill Impairments during the Period		38.8	$ 162.6	$ 1,406.3
Ending Balance	$ 199.0	147.6	199.0
Goodwill, Other Increase (Decrease)		(12.6)	(723.9)
Fayetteville
Goodwill [Line Items]
Impairment of intangible assets				70.9
Goodwill [Roll Forward]
Beginning Balance		0.0	0.0
Goodwill Impairments during the Period		0.0	0.0	72.5
Ending Balance	0.0	0.0	0.0	0.0
Marcellus
Goodwill [Roll Forward]
Beginning Balance		0.0	8.6
Goodwill Impairments during the Period		0.0	8.6	0.0
Ending Balance	0.0	0.0	0.0	8.6
Arrow
Goodwill [Roll Forward]
Beginning Balance		45.9	45.9
Goodwill Impairments during the Period		0.0	0.0	0.0
Ending Balance	45.9	45.9	45.9	45.9
Northeast Storage and Transportation
Goodwill [Roll Forward]
Beginning Balance		0.0	726.3
Goodwill Impairments during the Period		0.0	0.0	0.0
Goodwill, Written off Related to Sale of Business Unit		(726.3)
Ending Balance	0.0	0.0	0.0	726.3
COLT
Goodwill [Roll Forward]
Beginning Balance		0.0	44.9
Goodwill Impairments during the Period		0.0	44.9	623.4
Ending Balance	0.0	0.0	0.0	44.9
West Coast
Goodwill [Line Items]
Impairment of intangible assets		0.8
Goodwill [Roll Forward]
Beginning Balance		2.4	0.0
Goodwill Impairments during the Period		2.4	0.0	85.9
Goodwill, Acquired During Period		2.4
Ending Balance	2.4	0.0	2.4	0.0
Supply and Logistics
Goodwill [Roll Forward]
Beginning Balance		101.7	167.2
Goodwill Impairments during the Period		0.0	65.5	99.0
Ending Balance	101.7	101.7	101.7	167.2
Storage and Terminals
Goodwill [Roll Forward]
Beginning Balance		36.4	50.5
Goodwill Impairments during the Period		36.4	14.1	53.7
Ending Balance	36.4	0.0	36.4	50.5
US Salt
Goodwill [Roll Forward]
Beginning Balance		12.6	12.6
Goodwill Impairments during the Period		0.0	0.0	0.0
Goodwill, Written off Related to Sale of Business Unit		(12.6)
Ending Balance	12.6	0.0	12.6	12.6
Trucking
Goodwill [Line Items]
Impairment of intangible assets			31.4
Goodwill [Roll Forward]
Beginning Balance		0.0	29.5
Goodwill Impairments during the Period		0.0	29.5	148.4
Ending Balance	0.0	0.0	0.0	29.5
Haynesville
Goodwill [Line Items]
Impairment of intangible assets				6.0
Barnett
Goodwill [Line Items]
Impairment of intangible assets				238.9
Goodwill [Roll Forward]
Beginning Balance		0.0	0.0
Goodwill Impairments during the Period		0.0	0.0	257.2
Ending Balance	0.0	0.0	0.0	0.0
Watkins Glen
Goodwill [Roll Forward]
Beginning Balance		0.0	0.0
Goodwill Impairments during the Period		0.0	0.0	66.2
Ending Balance	0.0	0.0	0.0	0.0
CMLP
Goodwill [Roll Forward]
Beginning Balance		199.0	1,085.5
Goodwill Impairments during the Period		38.8	162.6	1,149.1
Ending Balance	199.0	147.6	199.0	1,085.5
Goodwill, Other Increase (Decrease)		(12.6)	(723.9)
Crestwood Equity Partners LP
Goodwill [Roll Forward]
Beginning Balance		199.0	1,085.5
Goodwill Impairments during the Period		38.8	162.6	1,406.3
Ending Balance	199.0	147.6	199.0	1,085.5
Marketing Supply and Logistics
Goodwill [Line Items]
Consideration transferred	7.2
Goodwill [Roll Forward]
Beginning Balance		153.1
Goodwill Impairments during the Period		38.8	109.1	453.2
Ending Balance	153.1	101.7	153.1
Marketing Supply and Logistics \| CMLP
Goodwill [Roll Forward]
Beginning Balance		153.1
Goodwill Impairments during the Period		38.8	109.1	$ 453.2
Ending Balance	$ 153.1	$ 101.7	$ 153.1

Divestitures (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
Divestitures (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Decrease in Intangible Assets		$ (8.5)
US Salt, LLC \| Marketing Supply and Logistics
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 Information (Property, Plant And Equipment) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 2,285.2	$ 2,555.4
Less: accumulated depreciation and depletion	464.4	457.8
Property, plant and equipment, net	1,820.8	2,097.6
Depletion	0.7
Loss on long-lived assets, net	(65.6)	(65.6)	$ (821.2)
Crestwood Equity Partners LP
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,285.2	2,555.4
Less: accumulated depreciation and depletion	464.4	457.8
Property, plant and equipment, net	1,820.8	2,097.6
Depreciation	135.9	154.8	195.1
Interest Costs Capitalized	2.9	0.7	2.5
Crestwood Equity Partners LP \| Gathering systems and pipelines and related assets
Property, Plant and Equipment [Line Items]
Property, plant and equipment	678.0	639.4
Crestwood Equity Partners LP \| Facilities and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,141.4	1,328.3
Crestwood Equity Partners LP \| Buildings, land, rights-of-way, storage rights and easements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	319.1	315.4
Crestwood Equity Partners LP \| Vehicles
Property, Plant and Equipment [Line Items]
Property, plant and equipment	37.3	45.7
Crestwood Equity Partners LP \| Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment	87.5	85.9
Crestwood Equity Partners LP \| Salt deposits
Property, Plant and Equipment [Line Items]
Property, plant and equipment	0.0	120.5
Crestwood Equity Partners LP \| Office furniture and fixtures
Property, Plant and Equipment [Line Items]
Property, plant and equipment	21.9	20.2
CMLP
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,615.3	2,885.5
Less: accumulated depreciation and depletion	607.8	587.1
Property, plant and equipment, net	2,007.5	2,298.4
Depreciation	150.0	168.9	186.7
Loss on long-lived assets, net	(65.6)	(65.6)	$ (227.8)
CMLP \| Gathering systems and pipelines and related assets
Property, Plant and Equipment [Line Items]
Property, plant and equipment	820.9	782.3
CMLP \| Facilities and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,326.5	1,513.4
CMLP \| Buildings, land, rights-of-way, storage rights and easements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	322.8	319.1
CMLP \| Vehicles
Property, Plant and Equipment [Line Items]
Property, plant and equipment	35.5	44.0
CMLP \| Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment	87.5	85.9
CMLP \| Salt deposits
Property, Plant and Equipment [Line Items]
Property, plant and equipment	0.0	120.5
CMLP \| Office furniture and fixtures
Property, Plant and Equipment [Line Items]
Property, plant and equipment	22.1	$ 20.3
US Salt
Property, Plant and Equipment [Line Items]
Loss on long-lived assets, net	33.6
Arrow and Marcellus
Property, Plant and Equipment [Line Items]
Loss on long-lived assets, net	$ 14.4

Certain Balance Sheet Information (Intangible Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Finite-Lived Intangible Assets [Line Items]
Less: accumulated amortization	$ 191.6	$ 241.2
Crestwood Equity Partners LP
Finite-Lived Intangible Assets [Line Items]
Amortization of Intangible Assets	53.7	72.5	$ 102.8
Intangible assets, Gross	788.8	898.6
Less: accumulated amortization	191.6	241.2
Total intangible assets, net	597.2	657.4
Crestwood Equity Partners LP \| Customer accounts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	438.9	541.9
Less: accumulated amortization	89.8	162.4
Crestwood Equity Partners LP \| Covenants not to compete
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	0.0	1.0
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	82.0	63.2
Crestwood Equity Partners LP \| Trademarks
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	24.7	30.5
Less: accumulated amortization	19.8	15.6
CMLP
Finite-Lived Intangible Assets [Line Items]
Amortization of Intangible Assets	50.6	69.3	$ 89.6
Intangible assets, Gross	773.3	883.1
Less: accumulated amortization	177.6	230.2
Total intangible assets, net	595.7	652.9
CMLP \| Customer accounts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	438.9	541.9
Less: accumulated amortization	89.8	162.4
CMLP \| Covenants not to compete
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	0.0	1.0
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	5.8	4.6
CMLP \| Trademarks
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	9.2	15.0
Less: accumulated amortization	$ 82.0	$ 63.2

Certain Balance Sheet Information (Amortization and Interest Expense, Fiscal Year Maturity) (Details) $ in Millions	Dec. 31, 2017 USD ($)
Crestwood Equity Partners LP
Finite-Lived Intangible Assets [Line Items]
2018	$ 43.4
2019	41.7
2020	41.7
2021	41.7
2022	41.7
CMLP
Finite-Lived Intangible Assets [Line Items]
2018	42.0
2019	41.7
2020	41.7
2021	41.7
2022	$ 41.7

Certain Balance Sheet Information (Accrued Expenses and Other Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	$ 56.6	$ 46.5
Accrued expenses and other liabilities	105.9	90.5
Accrued property taxes	4.8	4.2
Accrued natural gas purchases	0.0	4.9
Income tax payable	0.3	1.6
Interest payable	20.3	22.8
Accrued additions to property, plant and equipment	22.3	1.7
Capital leases	1.0	1.3
Deferred revenue	0.6	7.5
Total accrued expenses and other liabilities	105.9	90.5
CMLP
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	55.5	45.1
Accrued expenses and other liabilities	104.7	87.9
Accrued property taxes	4.8	4.2
Accrued natural gas purchases	0.0	4.9
Income tax payable	0.3	0.4
Interest payable	20.3	22.8
Accrued additions to property, plant and equipment	22.2	1.7
Capital leases	1.0	1.3
Deferred revenue	0.6	7.5
Total accrued expenses and other liabilities	$ 104.7	$ 87.9

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Net asset retirement obligation at January 1	$ 27.8	$ 26.4
Liabilities incurred	0.0	1.0
Liabilities settled	(1.2)	(1.2)
Accretion expense	(1.4)	(1.6)
Change in estimate	(0.5)	0.0
Net asset retirement obligation at December 31	$ 27.5	$ 27.8

Investments in Unconsolidated Affiliates Investments in Unconsolidated Affiliates Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution	$ 107.6	$ 53.9	$ 21.8
Payments to Acquire Equity Method Investments Cash and Noncash Consideration	127.4		41.8
Payments to Acquire Equity Method Investments	58.0	12.4	42.0
Equity Method Investment, Summarized Financial Information, Current Assets	136.4	107.4
Equity Method Investment, Summarized Financial Information, Revenue	350.4	226.9	104.7
Equity Method Investment Summarized Financial Information Operating Expenses	221.3	158.0	79.5
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	130.0	68.8	24.9
Investments in unconsolidated affiliates	1,183.0	1,115.4
Earnings (loss) from unconsolidated affiliates, net	47.8	31.5	(60.8)
Equity Method Investment, Summarized Financial Information, Noncurrent Assets	2,566.5	2,516.1
Equity Method Investment, Summarized Financial Information, Current Liabilities	60.4	29.2
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities	95.0	78.5
Equity Method Investment Summarized Financial Information, Equity	2,547.5	2,515.8
Goodwill impairment	38.8	162.6	1,406.3
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution	47.3	16.0	0.0
Payments to Acquire Equity Method Investments	0.8	0.0	0.0
Equity Method Investment, Summarized Financial Information, Current Assets	55.1	57.0
Equity Method Investment, Summarized Financial Information, Revenue	168.6	99.3	0.0
Equity Method Investment Summarized Financial Information Operating Expenses	77.7	44.1	0.0
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	91.1	55.3	0.0
Difference between carrying amount and underlying equity	$ 51.4
Equity method ownership percentage	50.00%
Investments in unconsolidated affiliates	$ 849.8	871.0
Earnings (loss) from unconsolidated affiliates, net	25.3	15.9	0.0
Equity Method Investment, Summarized Financial Information, Noncurrent Assets	1,765.4	1,807.6
Equity Method Investment, Summarized Financial Information, Current Liabilities	7.0	6.0
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities	1.4	4.1
Equity Method Investment Summarized Financial Information, Equity	1,812.1	1,854.5
Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution	26.3	27.4	12.5
Equity Method Investment, Summarized Financial Information, Revenue	181.8	127.6	104.7
Equity Method Investment Summarized Financial Information Operating Expenses	143.6	113.9	79.5
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	38.9	13.5	24.9
Difference between carrying amount and underlying equity	$ 0.7
Equity method ownership percentage	50.00%
Investments in unconsolidated affiliates	$ 184.9	197.2
Earnings (loss) from unconsolidated affiliates, net	10.5	20.8	(43.4)
Goodwill impairment			51.4
Other Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Summarized Financial Information, Current Assets	81.3	50.4
Equity Method Investment, Summarized Financial Information, Noncurrent Assets	801.1	708.5
Equity Method Investment, Summarized Financial Information, Current Liabilities	53.4	23.2
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities	93.6	74.4
Equity Method Investment Summarized Financial Information, Equity	735.4	661.3
Crestwood Permian Basin Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution	23.4	0.0	0.0
Payments to Acquire Equity Method Investments Cash and Noncash Consideration	$ 117.5
Payments to Acquire Equity Method Investments		0.0	0.0
Equity method ownership percentage	50.00%
Investments in unconsolidated affiliates	$ 102.0	(0.5)
Earnings (loss) from unconsolidated affiliates, net	8.4	(0.5)	0.0
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution	9.0	8.5	7.4
Payments to Acquire Equity Method Investments	5.6	11.0	5.7
Difference between carrying amount and underlying equity	26.5
Amortization	$ 1.3	1.3	1.3
Equity method ownership percentage	50.01%
Investments in unconsolidated affiliates	$ 37.8	39.0
Earnings (loss) from unconsolidated affiliates, net	2.2	(0.3)	2.5
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution	1.6	2.0	1.9
Payments to Acquire Equity Method Investments	0.0	0.0	10.7
Difference between carrying amount and underlying equity	6.4
Income (loss) from Equity Method Investments, Capital Adjustment			3.2
Amortization	$ 0.6	1.6
Equity method ownership percentage	50.01%
Investments in unconsolidated affiliates	$ 8.5	8.7
Earnings (loss) from unconsolidated affiliates, net	1.4	(4.4)	(19.9)
Goodwill impairment		5.8	23.4
RKI Exploration and Production, LLC's \| Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Amortization	$ 0.1	$ 0.1	$ 3.0

Investments in Unconsolidated Affiliates (Details) $ in Millions				1 Months Ended		12 Months Ended
	Jan. 01, 2018 USD ($)	Jun. 21, 2017 USD ($)	Jun. 03, 2016 USD ($)	Jan. 31, 2018 USD ($)	Oct. 31, 2017 USD ($)	Dec. 31, 2017 USD ($) a	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments						$ 58.0	$ 12.4	$ 42.0
Investments in unconsolidated affiliates						1,183.0	1,115.4
Earnings (loss) from unconsolidated affiliates, net						47.8	31.5	(60.8)
Net proceeds from sale of assets						225.2	972.7	2.7
Loss on long-lived assets, net						(65.6)	(65.6)	(821.2)
Estimated Cost to Build						180.0
Payments to Acquire Property, Plant, and Equipment						188.4	100.7	182.7
Contribution of Property		$ 69.0
Related Party Transaction, Expenses from Transactions with Related Party						22.3	8.1	3.3
Proceeds from Equity Method Investment, Distribution, Return of Capital						59.9	14.8	9.3
Proceeds from Equity Method Investment, Distribution						107.6	53.9	21.8
Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates						184.9	197.2
Earnings (loss) from unconsolidated affiliates, net						10.5	20.8	(43.4)
Difference between carrying amount and underlying equity						$ 0.7
Equity method ownership percentage						50.00%
Related Party Transaction, Expenses from Transactions with Related Party						$ 0.4	0.4	0.5
Proceeds from Equity Method Investment, Distribution						26.3	27.4	12.5
Jackalope Gas Gathering Services, LLC \| Subsequent Event
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution	$ 7.4
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments						5.6	11.0	5.7
Investments in unconsolidated affiliates						37.8	39.0
Earnings (loss) from unconsolidated affiliates, net						2.2	(0.3)	2.5
Difference between carrying amount and underlying equity						26.5
Amortization						$ 1.3	1.3	1.3
Equity method ownership percentage						50.01%
Related Party Transaction, Expenses from Transactions with Related Party						$ 3.5	2.7	2.8
Proceeds from Equity Method Investment, Distribution						9.0	8.5	7.4
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments						0.0	0.0	10.7
Investments in unconsolidated affiliates						8.5	8.7
Earnings (loss) from unconsolidated affiliates, net						1.4	(4.4)	(19.9)
Difference between carrying amount and underlying equity						6.4
Amortization						$ 0.6	1.6
Equity method ownership percentage						50.01%
Proceeds from Equity Method Investment, Distribution						$ 1.6	2.0	1.9
Powder River Basin Industrial Complex, LLC \| Subsequent Event
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution				$ 0.3
Crestwood Permian Basin Holdings
Schedule of Equity Method Investments [Line Items]
Percentage of Available Cash Distributed						100.00%
Difference between carrying amount and underlying equity						$ 11.6
Net proceeds from sale of assets					$ 37.9
Related Party Transaction, Expenses from Transactions with Related Party						$ 10.0
Proceeds from Equity Method Investment, Distribution					$ 18.9
Crestwood Permian Basin Holdings \| Subsequent Event
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution				4.3
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Percentage of Available Cash Distributed						35.00%
Payments to Acquire Equity Method Investments						$ 0.8	0.0	0.0
Investments in unconsolidated affiliates						849.8	871.0
Contingent consideration, noncurrent liability						57.0
Earnings (loss) from unconsolidated affiliates, net						25.3	15.9	0.0
Difference between carrying amount and underlying equity						$ 51.4
Net proceeds from sale of assets							3.0
Equity method ownership percentage						50.00%
Related Party Transaction, Expenses from Transactions with Related Party						$ 8.4	5.0
Proceeds from Equity Method Investment, Distribution						47.3	16.0	0.0
Stagecoach Gas Services LLC \| Subsequent Event
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Distribution				$ 11.3
RKI Exploration and Production, LLC's \| Jackalope Gas Gathering Services, LLC
Schedule of Equity Method Investments [Line Items]
Amortization						$ 0.1	0.1	3.0
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						$ 3.5	1.4	25.4
Crestwood Equity Partners LP \| Crestwood Permian Basin Holdings
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage						50.00%
SWEPI LP \| Crestwood Permian Basin Holdings
Schedule of Equity Method Investments [Line Items]
Area of Land \| a						100,000
Payments to Acquire Property, Plant, and Equipment						$ 84.3
SWEPI LP \| Crestwood Permian Basin LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage					50.00%
Crestwood New Mexico Pipeline LLC [Member]
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]
Percentage of voting interests acquired						50.00%
First Reserve Management, L.P. \| Crestwood Permian Basin Holdings
Schedule of Equity Method Investments [Line Items]
Capital Commitment to Acquire Equity Method Investment		$ 151.0
CEGP \| Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Percentage of Available Cash Distributed						65.00%
Net proceeds from sale of assets			$ 975.0				975.0
CMLP
Schedule of Equity Method Investments [Line Items]
Payments to Acquire Equity Method Investments						$ 58.0	12.4	41.8
Investments in unconsolidated affiliates						1,183.0	1,115.4
Earnings (loss) from unconsolidated affiliates, net						47.8	31.5	(60.8)
Net proceeds from sale of assets						225.2	972.7	2.7
Loss on long-lived assets, net						(65.6)	(65.6)	(227.8)
Payments to Acquire Property, Plant, and Equipment						188.4	100.7	182.7
Proceeds from Equity Method Investment, Distribution, Return of Capital						$ 59.9	14.8	$ 9.3
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%				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%

Risk Management (Notional Amounts and Terms of Company's Derivative Financial Instruments) (Details) - bbl bbl in Millions	Dec. 31, 2017	Dec. 31, 2016
Propane, crude and heating oil (MMBbls) \| Fixed Price Payor
Derivative [Line Items]
Propane, crude and heating oil (MMBbls)	15.3	13.1
Propane, crude and heating oil (MMBbls) \| Fixed Price Receiver
Derivative [Line Items]
Propane, crude and heating oil (MMBbls)	17.5	15.1
Natural Gas [Member] \| Fixed Price Payor
Derivative [Line Items]
Propane, crude and heating oil (MMBbls)	780.0	0.0
Natural Gas [Member] \| Fixed Price Receiver
Derivative [Line Items]
Propane, crude and heating oil (MMBbls)	660.0	0.0

Risk Management (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Derivative [Line Items]
Collateral posted for commodity derivative instruments	$ 3.7	$ 4.3
Price Risk Contracts \| Maximum
Derivative [Line Items]
Remaining maturity	34 months
Percent of contracts expiring in next twelve months	88.00%
ERROR in label resolution.
Derivative [Line Items]
Aggregate fair value of commodity derivative instruments	$ 28.9	13.9
Collateral posted for commodity derivative instruments	0.1	0.1
ERROR in label resolution.
Derivative [Line Items]
Derivative Asset	27.2	14.3
ERROR in label resolution.
Derivative [Line Items]
NYMEX margin deposit	5.6	4.2
Products and services sold
Derivative [Line Items]
Gain (Loss) on derivative instruments not designated as hedging	$ 31.2	$ 7.8	$ 18.9

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, 2017	Dec. 31, 2016
Senior Notes, 2020
Debt Instrument [Line Items]
Carrying Amount	$ 0.0	$ 340.6
Fair Value	0.0	350.2
Senior Notes, 2022
Debt Instrument [Line Items]
Carrying Amount	0.0	429.3
Fair Value	0.0	447.3
Senior Notes, 2023
Debt Instrument [Line Items]
Carrying Amount	692.1	690.6
Debt Instrument, Fair Value Disclosure	728.8	722.6
Senior Notes, 2025
Debt Instrument [Line Items]
Carrying Amount	492.3	0.0
Debt Instrument, Fair Value Disclosure	$ 517.9	$ 0.0

Fair Value Measurements (Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Assets, Fair Value Disclosure [Abstract]
Assets from price risk management	$ 103.3	$ 85.0
Assets from price risk management, Total	7.2	6.3
SPH units	3.5	4.3
Assets, Fair Value Disclosure, Excluding Netting Adjustments	106.8	89.3
Netting Agreements	(74.6)	(67.8)
Derivative Asset, Fair Value of Collateral	(21.5)	(10.9)
Total assets at fair value	10.7	10.6
Liabilities, Fair Value Disclosure [Abstract]
Liabilities from price risk management	119.6	92.9
Liabilities from price risk management, Total	48.9	28.6
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments		92.9
Netting Agreements	(74.6)	(67.8)
Derivative Liability, Fair Value of Collateral	3.9	3.5
Total liabilities at fair value		28.6
Level 1
Assets, Fair Value Disclosure [Abstract]
Assets from price risk management	1.1	0.6
SPH units	3.5	4.3
Assets, Fair Value Disclosure, Excluding Netting Adjustments	4.6	4.9
Liabilities, Fair Value Disclosure [Abstract]
Liabilities from price risk management	1.4	2.7
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	1.4	2.7
Level 2
Assets, Fair Value Disclosure [Abstract]
Assets from price risk management	102.2	84.4
SPH units	0.0	0.0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	102.2	84.4
Liabilities, Fair Value Disclosure [Abstract]
Liabilities from price risk management	118.2	90.2
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	118.2	90.2
Level 3
Assets, Fair Value Disclosure [Abstract]
Assets from price risk management	0.0	0.0
SPH units	0.0	0.0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	0.0	0.0
Liabilities, Fair Value Disclosure [Abstract]
Liabilities from price risk management	0.0	0.0
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	$ 0.0	$ 0.0

Long-Term Debt (Components Of Long-Term Debt) (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Carrying Amount	$ 0.0
Debt Issuance Costs, Net	28.4	$ 34.0
Less: current portion	0.9	1.0
Total long-term debt	1,491.3	1,522.7
Crestwood Midstream 2020 Senior Notes
Debt Instrument [Line Items]
Fair value adjustment	0.0	1.8
Crestwood Midstream Revolver \| Revolving Credit Facility
Debt Instrument [Line Items]
Credit agreement outstanding carrying value	318.2	77.0
Senior Notes, 2022
Debt Instrument [Line Items]
Debt Issuance Costs, Net	6.8
Senior Notes, 2025 \| Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Carrying Amount	500.0
CMLP
Debt Instrument [Line Items]
Carrying Amount		338.8
Obligations under noncompetition agreements and notes to former owners of businesses acquired	2.4	3.7
Debt, Long-term and Short-term, Combined Amount	1,492.2	1,523.7
Less: current portion	0.9	1.0
Total long-term debt	1,491.3	1,522.7
CMLP \| Crestwood Midstream 2022 senior unsecured notes
Debt Instrument [Line Items]
Carrying Amount		436.4
CMLP \| Senior Notes, 2022 \| Crestwood Midstream 2022 senior unsecured notes
Debt Instrument [Line Items]
Carrying Amount	0.0
CMLP \| Senior Notes, 2023 \| Crestwood Midstream 2022 senior unsecured notes
Debt Instrument [Line Items]
Carrying Amount	700.0	700.0
CMLP \| Senior Notes, 2025 \| Crestwood Midstream 2022 senior unsecured notes
Debt Instrument [Line Items]
Carrying Amount	$ 500.0	$ 0.0

Long-Term Debt (Narrative) (Detail)														1 Months Ended		9 Months Ended			12 Months Ended
Long-Term Debt (Narrative) (Detail)	Nov. 14, 2017 USD ($)	Aug. 14, 2017 USD ($)	May 15, 2017 USD ($)	Feb. 14, 2017 USD ($)	Nov. 14, 2016 USD ($)	Aug. 12, 2016 USD ($)	May 13, 2016 USD ($)	Feb. 12, 2016 USD ($)	Nov. 13, 2015 USD ($)	Sep. 30, 2015 USD ($)	Aug. 14, 2015 USD ($)	May 15, 2015 USD ($)	Feb. 13, 2015 USD ($)	Jun. 30, 2016 USD ($)	Apr. 30, 2015 USD ($)	Sep. 30, 2017 USD ($)	Sep. 30, 2016 USD ($)	Sep. 30, 2015 USD ($)	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Debt Instrument [Line Items]
Amount of Restricted Net Assets for Consolidated and Unconsolidated Subsidiaries																			$ 2,195,400,000
Distribution Made to Limited Partner, Cash Distributions Paid	$ 42,200,000	$ 41,800,000	$ 41,800,000	$ 41,800,000	$ 41,400,000	$ 41,400,000	$ 41,400,000	$ 95,600,000	$ 94,300,000		$ 25,700,000	$ 25,700,000	$ 25,800,000						167,600,000	$ 219,800,000	$ 171,500,000
Gains (Losses) on Extinguishment of Debt																	$ 10,000,000		(37,700,000)	10,000,000	(20,000,000)
Debt Issuance Costs, Net																			28,400,000	34,000,000
Carrying amount																			0
Repayments of Senior Debt														$ 312,900,000
Crestwood Equity Partners LP
Debt Instrument [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid										$ 378,300,000								$ 378,300,000
CMLP
Debt Instrument [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid											$ 74,300,000	$ 74,300,000	$ 74,300,000							222,900,000
Gains (Losses) on Extinguishment of Debt																			(37,700,000)	10,000,000	$ (18,900,000)
Carrying amount																				338,800,000
Senior Notes, 2019
Debt Instrument [Line Items]
Gains (Losses) on Extinguishment of Debt															$ 17,100,000
Revolving Loan Facility \| CMLP
Debt Instrument [Line Items]
Credit agreement outstanding carrying value																			1,500,000,000	1,000,000,000
Crestwood Midstream 2020 Senior Notes
Debt Instrument [Line Items]
Fair value adjustment																			$ 0	1,800,000
Crestwood Midstream 2022 senior unsecured notes \| CMLP
Debt Instrument [Line Items]
Carrying amount																				436,400,000
Crestwood Midstream Revolver
Debt Instrument [Line Items]
Gains (Losses) on Extinguishment of Debt																		$ 1,800,000
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	0
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																			0.0030
Crestwood Midstream Credit Facility \| Maximum
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Amount																			0.0050
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 rate, stated percentage																			6.125%
Interest Paid														2,600,000					$ 1,000,000
Extinguishment of Debt, Amount														163,600,000
Senior Notes, 2022 \| Crestwood Midstream 2022 senior unsecured notes \| CMLP
Debt Instrument [Line Items]
Carrying amount																			$ 0
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																			$ 318,200,000	77,000,000
Letters of credit outstanding																			$ 52,200,000	$ 64,000,000
Total funded debt to consolidated EBITDA																			4.14
Consolidated EBITDA to consolidated interest expense																			4.14
Senior Secured Leverage Ratio																			0.86
Weighted average interest rate																			4.11%	3.23%
Unused borrowing capacity																			$ 499,300,000
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																			3.94%	3.21%
Crestwood Midstream Revolver \| Revolving Credit Facility \| Maximum
Debt Instrument [Line Items]
Weighted average interest rate																			6.00%	5.25%
Crestwood Midstream Revolver \| Revolving Credit Facility \| Line of Credit
Debt Instrument [Line Items]
Proceeds from Issuance of Debt										$ 720,000,000
Crestwood Midstream Revolver \| Bridge Loan
Debt Instrument [Line Items]
Credit agreement outstanding carrying value																			$ 25,000,000
Senior Notes, 2019 \| Crestwood Midstream 2019 Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage															7.75%
Interest Paid															$ 500,000
Call Premium On Debt Redemption															13,600,000
Repayments of Senior Debt															364,100,000
Senior Notes, 2019 \| Crestwood Midstream 2019 Senior Notes \| CMLP
Debt Instrument [Line Items]
Long-term Debt															$ 350,000,000
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 rate, stated percentage																			6.00%
Interest Paid														4,500,000					$ 5,100,000
Extinguishment of Debt, Amount														$ 161,200,000
Obligations Under Noncompetition Agreements And Notes To Former Owners Of Businesses Acquired \| CMLP
Debt Instrument [Line Items]
Total payments due																			2,700,000	$ 4,200,000
Obligations under noncompete agreements, unamortized discount																			$ 300,000	$ 500,000
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																			1.75%
Eurodollar [Member] \| Revolving Credit Facility \| Crestwood Midstream Credit Facility \| Maximum
Debt Instrument [Line Items]
Variable interest rate																			2.75%
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																			0.75%
Eurodollar [Member] \| Revolving Credit Facility \| Crestwood Midstream Revolver \| Maximum
Debt Instrument [Line Items]
Variable interest rate																			1.75%
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 Long Term Debt) (Details) - CMLP $ in Millions	Dec. 31, 2017 USD ($)
Debt Instrument [Line Items]
2018	$ 0.9
2019	0.9
2020	318.4
2021	0.2
2022	0.2
Thereafter	1,200.0
Total debt	$ 1,520.6

Earnings Per Limited Partner Unit (Schedule of Reconciliation of Earnings Per Share) (Details) - shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Preferred Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of earnings per share	7,007,917	6,433,127	1,547,060
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
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	7,146,663	7,548,624	2,760,794

Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
Income Taxes (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Contingency [Line Items]
Net Deferred Tax Liability, Decrease Due To Regulation	$ 1.3
Deferred:
Total deferred	2.1	$ 3.1	$ 3.6
(Provision) benefit for income taxes	0.8	(0.3)	1.4
Crestwood Equity Partners LP
Current:
Federal	(1.1)	(3.2)	(1.6)
State	(0.2)	(0.2)	(0.6)
Total current	(1.3)	(3.4)	(2.2)
Deferred:
Federal	2.1	3.0	2.9
State	0.0	0.1	0.7
Total deferred	2.1	3.1	3.6
(Provision) benefit for income taxes	0.8	(0.3)	1.4
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 acquired company	(3.5)	(5.5)
Deferred Tax Liabilities, Gross	(3.5)	(5.5)
Total deferred tax liability	(3.3)	(5.3)
CMLP
Current:
Federal	0.0	0.0	0.0
State	0.0	0.2	(0.3)
Total current	0.0	0.2	(0.3)
Deferred:
Federal	0.0	0.0	0.0
State	0.0	(0.2)	0.3
Total deferred	0.0	(0.2)	0.3
(Provision) benefit for income taxes	0.0	0.0	$ 0.0
Deferred tax asset:
Basis difference in stock of company	0.0	0.0
Total deferred tax asset	0.0	0.0
Deferred tax liability:
Basis difference in stock of acquired company	(0.7)	(0.7)
Deferred Tax Liabilities, Gross	(0.7)	(0.7)
Total deferred tax liability	$ (0.7)	$ (0.7)

Partners' Capital (Schedule of Issuance of Units) (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2017	Dec. 31, 2016
Partners' Capital [Abstract]
Partners' Capital Account, Units, Sold in Public Offering	195,753	437,518	633,271
Proceeds from Issuance or Sale of Equity	$ 4.6	$ 10.6	$ 15.2
Units	70,721,563		70,721,563	69,499,741

Partners' Capital (Narrative) (Details) $ / shares in Units, $ in Millions																															1 Months Ended	9 Months Ended	12 Months Ended
	Feb. 14, 2018 USD ($) $ / shares	Feb. 07, 2018	Nov. 14, 2017 USD ($) $ / shares	Nov. 07, 2017	Aug. 14, 2017 USD ($) $ / shares	Aug. 07, 2017	May 15, 2017 USD ($) $ / shares	May 08, 2017	Feb. 14, 2017 USD ($) $ / shares	Feb. 07, 2017	Nov. 14, 2016 USD ($) $ / shares	Nov. 07, 2016	Aug. 12, 2016 USD ($) $ / shares	Aug. 05, 2016	May 13, 2016 USD ($) $ / shares	May 06, 2016	Feb. 12, 2016 USD ($) $ / shares	Feb. 05, 2016	Nov. 13, 2015 USD ($) $ / shares	Nov. 06, 2015	Sep. 30, 2015 USD ($) shares	Aug. 14, 2015 USD ($) $ / shares	Aug. 10, 2015 USD ($)	Aug. 07, 2015	May 15, 2015 USD ($) $ / shares	May 08, 2015	Feb. 13, 2015 USD ($) $ / shares	Feb. 06, 2015	Jan. 30, 2015 shares	Jun. 17, 2014 USD ($) $ / shares	Dec. 31, 2017 USD ($) $ / shares shares	Sep. 30, 2015 USD ($) shares	Dec. 31, 2017 USD ($) $ / shares shares	Dec. 31, 2016 USD ($) shares	Dec. 31, 2015 USD ($) shares	Jun. 15, 2016 shares
Distribution Made to Member or Limited Partner [Line Items]
Distribution to limited partner, distribution date			Nov. 14, 2017		Aug. 14, 2017		May 15, 2017		Feb. 14, 2017		Nov. 14, 2016		Aug. 12, 2016		May 13, 2016		Feb. 12, 2016		Nov. 13, 2015			Aug. 14, 2015			May 15, 2015		Feb. 13, 2015
Conversion ratio																					2.75											2.75
Maximum Period For Distribution Of Available Cash																																	45 days
Distribution Made to Limited Partner, Cash Distributions Paid			$ 42.2		$ 41.8		$ 41.8		$ 41.8		$ 41.4		$ 41.4		$ 41.4		$ 95.6		$ 94.3			$ 25.7			$ 25.7		$ 25.8						$ 167.6	$ 219.8	$ 171.5
Per unit rate, in dollars per unit \| $ / shares			$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 1.3750		$ 1.3750			$ 1.3750			$ 1.3750		$ 1.3750
Distributions to partners																																	(167.6)	(219.8)	(171.5)
Payments to Acquire Equity Method Investments																																	58.0	12.4	42.0
Loss on contingent consideration																																	$ (57.0)	$ 0.0	$ 0.0
Distribution made to limited partners \| shares																																	4,724,030	5,815,170	1,372,573
Distributions paid to non-controlling partners																																	$ 15.2	$ 15.2	$ 234.2
Limited partners' units, issued \| shares																															70,721,563		70,721,563	69,499,741
Dividends, Paid-in-kind																																	$ 43.1	$ 53.0	12.5
Common Units Available for Issuance \| shares																																				7,290,552
Issuance of preferred equity of subsidiary																																	$ 0.0
Preferred units, outstanding \| shares																															71,257,445		71,257,445	66,533,415
Preferred units, issued \| shares																															71,257,445		71,257,445	66,533,415
Equity Offering Program Authorized Amount																																	$ 250.0
Equity Distribution Program Management Fee Percentage																																	2.00%
Payments of Stock Issuance Costs																																	$ 0.3
Distribution to limited partner, record date				Nov. 07, 2017		Aug. 07, 2017		May 08, 2017		Feb. 07, 2017		Nov. 07, 2016		Aug. 05, 2016		May 06, 2016		Feb. 05, 2016		Nov. 06, 2015				Aug. 07, 2015		May 08, 2015		Feb. 06, 2015
Payments for Repurchase of Redeemable Noncontrolling Interest																															$ 202.7		202.7	$ 0.0	0.0
Proceeds from Noncontrolling Interests																															$ 175.0		$ 175.0	0.0	0.0
Preferred Units, Class A
Distribution Made to Member or Limited Partner [Line Items]
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units																							$ 58.8
Partners' Capital Account, Private Placement of Units, Price Per Unit \| $ / shares																														$ 25.10			$ 9.13
Proceeds from Issuance of Preferred Limited Partners Units, Gross																							$ 60.0
Crestwood Equity Partners LP
Distribution Made to Member or Limited Partner [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid																					$ 378.3											$ 378.3
Preferred units, issued \| shares																					59,345,672											59,345,672
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																																	$ 15.2	15.2	11.3
Crestwood Gas Services GP, LLC [Member]
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]
Distribution to limited partner, distribution date																						Aug. 14, 2015			May 15, 2015		Feb. 13, 2015
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units																																	$ 0.0	0.0	58.8
Maximum Period For Distribution Of Available Cash																																	45 days
Distribution Made to General Partner, Cash Distributions Paid																																			31.4
Distribution Made to Limited Partner, Cash Distributions Paid																						$ 74.3			$ 74.3		$ 74.3							222.9
Dividends received from CMLP																																	$ 174.0	227.6	175.6
Per unit rate, in dollars per unit \| $ / shares																						$ 0.41			$ 0.41		$ 0.41
Distributions to partners																																	(189.2)	(242.8)	(819.5)
Payments to Acquire Equity Method Investments																																	58.0	12.4	41.8
Loss on contingent consideration																																	(57.0)	0.0	$ 0.0
Distribution made to limited partners \| shares																																			1,271,935
Dividends, Paid-in-kind																																			$ 31.9
Issuance of preferred equity of subsidiary																																	175.0
Preferred units, outstanding \| shares																					21,580,244											21,580,244
Distribution to limited partner, record date																								Aug. 07, 2015		May 08, 2015		Feb. 06, 2015
Payments for Repurchase of Redeemable Noncontrolling Interest																																	202.7	0.0
Proceeds from Noncontrolling Interests																																	175.0	0.0	0.0
Tres Palacios Holdings LLC
Distribution Made to Member or Limited Partner [Line Items]
Payments to Acquire Equity Method Investments																																	$ 5.6	11.0	5.7
Equity method ownership percentage																															50.01%		50.01%
Tres Palacios Holdings LLC \| CMLP
Distribution Made to Member or Limited Partner [Line Items]
Equity method ownership percentage																															50.01%		50.01%
Jackalope Gas Gathering Services, LLC
Distribution Made to Member or Limited Partner [Line Items]
Equity method ownership percentage																															50.00%		50.00%
Jackalope Gas Gathering Services, LLC \| Preferred Units
Distribution Made to Member or Limited Partner [Line Items]
Distribution made to limited partners \| shares																													3,680,570
Jackalope Gas Gathering Services, LLC \| Crestwood Niobrara LLC
Distribution Made to Member or Limited Partner [Line Items]
Payments to Acquire Equity Method Investments																																	$ 3.5	$ 1.4	25.4
Cash distribution
Distribution Made to Member or Limited Partner [Line Items]
Distributions paid to non-controlling partners																																			$ 222.9
Cash distribution \| Subsequent Event
Distribution Made to Member or Limited Partner [Line Items]
Distribution to limited partner, distribution date	Feb. 14, 2018
Distribution declared per limited partner unit \| $ / shares	$ 0.600
Distribution to limited partner, record date		Feb. 07, 2018
Preferred Partner
Distribution Made to Member or Limited Partner [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid																																	$ 15.0
Partners' Capital, Distribution Amount Per Share \| $ / shares																															$ 0.2567		$ 0.2567
Partners' Capital, Contingent Distribution Amount Per Share \| $ / shares																															0.2111		$ 0.2111
Partner's Capital, Unpaid Distribution, Accrual Percentage																																	2.8125%
Preferred Partner \| Subsequent Event
Distribution Made to Member or Limited Partner [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid	$ 15.0
Preferred Partner \| CMLP
Distribution Made to Member or Limited Partner [Line Items]
Partners' Capital, Distribution Amount Per Share \| $ / shares																															$ 0.5804		$ 0.5804
Partners' Capital Account, Private Placement of Units, Price Per Unit \| $ / shares																																	25.10
Subordinated Unit \| Limited Partners
Distribution Made to Member or Limited Partner [Line Items]
Limited partners' units, issued \| shares																																			438,789
Partners' Capital Account, Units, Cash Distribution Threshold, Quarterly Distribution \| $ / shares																																	1.30
Partners' Capital Account, Units, Conversion Threshold, Cumulative Distribution \| $ / shares																																	$ 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																																	175.0
Non-Controlling Partners \| CMLP
Distribution Made to Member or Limited Partner [Line Items]
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units																																			$ 0.0
Issuance of preferred equity of subsidiary																																	$ 175.0
Limited Partners \| CMLP
Distribution Made to Member or Limited Partner [Line Items]
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units																																			$ 0.0
Maximum \| Class A Purchasers \| Preferred Units, Class A
Distribution Made to Member or Limited Partner [Line Items]
Contribution from issuance of units																														$ 500.0

Partners' Capital (Schedule of Partnership Distributions) (Details) - USD ($) $ / shares in Units, $ in Millions																											12 Months Ended
	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	Nov. 13, 2015	Nov. 06, 2015	Aug. 14, 2015	Aug. 07, 2015	May 15, 2015	May 08, 2015	Feb. 13, 2015	Feb. 06, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure Partners Capital Summary Of Quarterly Distributions Of Available Cash [Abstract]
Distribution to limited partner, record date				Nov. 07, 2017		Aug. 07, 2017		May 08, 2017		Feb. 07, 2017		Nov. 07, 2016		Aug. 05, 2016		May 06, 2016		Feb. 05, 2016		Nov. 06, 2015		Aug. 07, 2015		May 08, 2015		Feb. 06, 2015
Distribution to limited partner, distribution date			Nov. 14, 2017		Aug. 14, 2017		May 15, 2017		Feb. 14, 2017		Nov. 14, 2016		Aug. 12, 2016		May 13, 2016		Feb. 12, 2016		Nov. 13, 2015		Aug. 14, 2015		May 15, 2015		Feb. 13, 2015
Distribution Made to Limited Partner, Distributions Paid, Per Unit			$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 1.3750		$ 1.3750		$ 1.3750		$ 1.3750		$ 1.3750
Distribution amount			$ 42.2		$ 41.8		$ 41.8		$ 41.8		$ 41.4		$ 41.4		$ 41.4		$ 95.6		$ 94.3		$ 25.7		$ 25.7		$ 25.8		$ 167.6	$ 219.8	$ 171.5
Cash distribution \| Subsequent Event
Disclosure Partners Capital Summary Of Quarterly Distributions Of Available Cash [Abstract]
Distribution to limited partner, record date		Feb. 07, 2018
Distribution to limited partner, distribution date	Feb. 14, 2018
Distribution declared per limited partner unit	$ 0.600

Partners' Capital Net Income (Loss) Attributable to NonControlling Partners (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Limited Partners' Capital Account [Line Items]
Net income (loss) attributable to non-controlling partners in subsidiary	$ 25.3	$ 24.2	$ (636.8)
CMLP
Limited Partners' Capital Account [Line Items]
Net income (loss) attributable to non-controlling partners in subsidiary	25.3	24.2	23.1
CMLP \| Preferred Units, Class A
Limited Partners' Capital Account [Line Items]
Net income (loss) attributable to non-controlling partners in subsidiary	0.0	0.0	23.1
Crestwood Niobrara LLC
Limited Partners' Capital Account [Line Items]
Net income (loss) attributable to non-controlling partners in subsidiary	25.3	24.2	23.1
Limited Partners \| CMLP
Limited Partners' Capital Account [Line Items]
Net income (loss) attributable to non-controlling partners in subsidiary	$ 0.0	$ 0.0	$ (683.0)

Partners' Capital Schedule of CMLP Partnership Distributions (Details) - USD ($) $ / shares in Units, $ in Millions																									12 Months Ended
	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	Nov. 13, 2015	Nov. 06, 2015	Aug. 14, 2015	Aug. 07, 2015	May 15, 2015	May 08, 2015	Feb. 13, 2015	Feb. 06, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Distribution to limited partner, record date		Nov. 07, 2017		Aug. 07, 2017		May 08, 2017		Feb. 07, 2017		Nov. 07, 2016		Aug. 05, 2016		May 06, 2016		Feb. 05, 2016		Nov. 06, 2015		Aug. 07, 2015		May 08, 2015		Feb. 06, 2015
Distribution to limited partner, distribution date	Nov. 14, 2017		Aug. 14, 2017		May 15, 2017		Feb. 14, 2017		Nov. 14, 2016		Aug. 12, 2016		May 13, 2016		Feb. 12, 2016		Nov. 13, 2015		Aug. 14, 2015		May 15, 2015		Feb. 13, 2015
Distribution Made to Limited Partner, Distributions Paid, Per Unit	$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 0.60		$ 1.3750		$ 1.3750		$ 1.3750		$ 1.3750		$ 1.3750
Distribution Made to Limited Partner, Cash Distributions Paid	$ 42.2		$ 41.8		$ 41.8		$ 41.8		$ 41.4		$ 41.4		$ 41.4		$ 95.6		$ 94.3		$ 25.7		$ 25.7		$ 25.8		$ 167.6	$ 219.8	$ 171.5
CMLP
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Distribution to limited partner, record date																				Aug. 07, 2015		May 08, 2015		Feb. 06, 2015
Distribution to limited partner, distribution date																			Aug. 14, 2015		May 15, 2015		Feb. 13, 2015
Distribution Made to Limited Partner, Distributions Paid, Per Unit																			$ 0.41		$ 0.41		$ 0.41
Distribution Made to Limited Partner, Cash Distributions Paid																			$ 74.3		$ 74.3		$ 74.3			$ 222.9

Equity Plans (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
Equity Plans (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Feb. 12, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 22.4	$ 16.0	$ 11.5
Employer matching contribution, percent	6.00%
Crestwood Long-Term Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common units to satisfy employee tax withholding obligations	206,600	57,508	26,095
Crestwood Long-Term Incentive Plan \| Restricted units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation costs not yet recognized	$ 23.7	$ 14.9
Subsequent Event \| Crestwood Long-Term Incentive Plan \| Restricted units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares reserved for future issuance				3,428,811
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%

Equity Plans (Schedule of Phantom and Restricted Unit Activity) (Details) - $ / shares													12 Months Ended
	Nov. 14, 2017	Aug. 14, 2017	May 15, 2017	Feb. 14, 2017	Nov. 14, 2016	Aug. 12, 2016	May 13, 2016	Feb. 12, 2016	Nov. 13, 2015	Aug. 14, 2015	May 15, 2015	Feb. 13, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Distribution to limited partner, distribution date	Nov. 14, 2017	Aug. 14, 2017	May 15, 2017	Feb. 14, 2017	Nov. 14, 2016	Aug. 12, 2016	May 13, 2016	Feb. 12, 2016	Nov. 13, 2015	Aug. 14, 2015	May 15, 2015	Feb. 13, 2015
Crestwood Long-Term Incentive Plan \| Restricted units
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													1,292,330	466,214	131,588
Unvested units - December 31													$ 24.67	$ 69.80	$ 132.10
Vested, units													(607,115)	(193,295)	(91,798)
Vested													$ 28.00	$ 76.82	$ 121.13
Granted, units													919,411	1,067,535	142,255
Granted													$ 25.69	$ 14.58	$ 55.25
Share-based Compensation Arrangement by Share-based Payment Award, Other Share Increase (Decrease)															226,401
Share Based Compensation Arrangement By Share Based Payment Award Other Shares Increase Decrease Weighted Average Grant Date Fair Value															$ 68.85
Canceled, units													(140,137)	(65,591)	(20,994)
Canceled													$ 23.73	$ 25.13	$ 89.97
Unvested units - December 31, units													1,830,096	1,292,330	466,214
Unvested units - December 31													$ 25.21	$ 24.67	$ 69.80
Crestwood Long-Term Incentive Plan \| Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Vested, units													(31,106)
Vested													$ 30.27
Granted, units													405,620
Granted													$ 30.21
Canceled, units													(24,756)
Canceled													$ 30.45
Crestwood Long-Term Incentive Plan \| Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Vested, units															(4,856)
Vested															$ 67.10
Granted, units													15,849	17,467	42,349
Granted													$ 25.02	$ 15.54	$ 62.31
Share-based Compensation Arrangement by Share-based Payment Award, Other Share Increase (Decrease)															41,269
Share Based Compensation Arrangement By Share Based Payment Award Other Shares Increase Decrease Weighted Average Grant Date Fair Value															$ 58.36
Employee Severance \| Crestwood Long-Term Incentive Plan \| Restricted units
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Canceled, units															(7,263)

Employee Benefit Plan (Details) - USD ($)	12 Months Ended
Employee Benefit Plan (Details) - USD ($)	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Postemployment Benefits [Abstract]
Defined Contribution Plan, Employer Matching Contribution, Percent	90.00%
Defined Benefit Plan, Employee Contributions, Statutory Maximum Per Employee	$ 18,000	$ 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	$ 4,000,000	$ 3,800,000	$ 4,000,000

Commitments and Contingencies (Narrative) (Details)		12 Months Ended
Commitments and Contingencies (Narrative) (Details)	Dec. 13, 2017 USD ($)	Dec. 31, 2017 USD ($) bbl Release	Dec. 31, 2016 USD ($)	Sep. 15, 2015 USD ($)	May 06, 2015 bbl
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Number of Plaintiffs		13
Accrued property taxes		$ 4,800,000	$ 4,200,000
Loss Contingency Accrual, at Carrying Value		2,100,000	100,000
Environmental Remediation Expense	$ 49,000
Estimated Environmental Costs	$ 173,000
Accrual for Environmental Loss Contingencies		1,900,000	2,100,000
Other Growth and Maintenance Contractual Purchase Obligations
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Firm Purchase Commitments		63,900,000
Commodity
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Firm Purchase Commitments		479,300,000
Crestwood Equity Partners LP
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Self-insurance reserves		13,600,000	15,600,000
Self-insurance reserve expected to be paid in next fiscal year		9,100,000
CMLP
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Accrued property taxes		4,800,000	4,200,000
Self-insurance reserves		11,600,000	$ 12,200,000
Self-insurance reserve expected to be paid in next fiscal year		$ 7,600,000
Maximum
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Number of Plaintiffs		150
Loss Contingency, Estimate of Possible Loss		$ 3,100,000		$ 1,100,000
Minimum
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Estimate of Possible Loss		$ 1,900,000
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 (Schedule of Future Minimum Lease Payments under Noncancelable Operatng Leases) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
2015	$ 35.2
2016	30.1
2017	23.2
2018	11.5
2019	7.7
Thereafter	18.8
Rent expense	34.2	$ 25.5	$ 37.4
Operating Leases, Future Minimum Payments Due	$ 126.5

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Related Party Transaction [Line Items]
Gathering and processing revenues at CEQP and CMLP	$ 1.8	$ 2.6	$ 3.9
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	22.3	8.1	3.3
Affiliated Entity
Related Party Transaction [Line Items]
Gathering and processing revenues at CEQP and CMLP	1.8	2.6	3.9
Gathering and processing costs of product sold at CEQP and CMLP(1)	15.3	17.7	28.9
General and administrative expenses charged by CEQP to CMLP, net(3)	19.4	13.0	49.5
CMLP
Related Party Transaction [Line Items]
Gathering and processing revenues at CEQP and CMLP	1.8	2.6	3.9
CMLP \| Affiliated Entity
Related Party Transaction [Line Items]
General and administrative expenses charged by CEQP to CMLP, net(3)	3.0	3.0	0.8
Related Party Transaction, Due from (to) Related Party [Abstract]
Accounts payable at CEQP	5.0	0.0
Crestwood Equity Partners LP
Related Party Transaction [Line Items]
Related Party Transaction, (Income) Expenses from Transactions with Related Party	(1.7)	(2.2)	0.4
Crestwood Equity Partners LP \| Affiliated Entity
Related Party Transaction, Due from (to) Related Party [Abstract]
Accounts receivable at CEQP and CMLP	7.1	5.6
Accounts payable at CEQP	7.4	2.5
Crestwood Long-Term Incentive Plan \| CMLP
Related Party Transaction [Line Items]
Allocated share based compensation expense	22.4	16.0	10.0
Crestwood Long-Term Incentive Plan \| Crestwood Holdings
Related Party Transaction [Line Items]
Allocated share based compensation expense	3.1	3.2	0.1
Stagecoach Gas Services LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	8.4	5.0
Tres Palacios Holdings LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	3.5	2.7	2.8
Crestwood Permian Basin Holdings
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	10.0
Jackalope Gas Gathering Services, LLC
Related Party Transaction, Due from (to) Related Party [Abstract]
Related Party Transaction, Expenses from Transactions with Related Party	$ 0.4	$ 0.4	$ 0.5

Segments (Narrative) (Details) $ in Millions	12 Months Ended
Segments (Narrative) (Details) $ in Millions	Dec. 31, 2017 USD ($)	Dec. 31, 2017	Dec. 31, 2017 segment	Dec. 31, 2017 reporting_units	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Revenue, Major Customer [Line Items]
Number of operating segments			3	3
Concentration Risk, Percentage		10.00%			10.00%	10.00%
Revenues	$ 3,880.9				$ 2,520.5	$ 2,632.8
Crestwood Equity Partners LP
Revenue, Major Customer [Line Items]
Earnings (Losses) Before Interest, Taxes, Depreciation and Amortization from Equity Method Investments	32.5				29.6	86.1
CMLP
Revenue, Major Customer [Line Items]
Revenues	$ 3,880.9				$ 2,520.5	$ 2,632.8

Segments (Reconciliation of Net Income (Loss) to EBITDA) (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Net loss		$ (166.6)	$ (192.1)	$ (2,303.7)
Interest and debt expense, net		(99.4)	(125.1)	(140.1)
(Gain) loss on modification/extinguishment of debt	$ (10.0)	37.7	(10.0)	20.0
(Provision) benefit for income taxes		(0.8)	0.3	(1.4)
Depreciation, amortization and accretion		191.7	229.6	300.1
EBITDA		161.4	152.9	(1,844.9)
CMLP
Segment Reporting Information [Line Items]
Net loss		(175.5)	(197.5)	(1,410.6)
Interest and debt expense, net		(99.4)	(125.1)	(130.5)
(Gain) loss on modification/extinguishment of debt		37.7	(10.0)	18.9
(Provision) benefit for income taxes		0.0	0.0	0.0
Depreciation, amortization and accretion		202.7	240.5	278.5
EBITDA		$ 164.3	$ 158.1	$ (982.7)

Segments (Summary Of Segment Information) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Operating revenues	$ 3,880.9	$ 2,520.5	$ 2,632.8
Intersegment Revenues	0.0	0.0	0.0
Costs of product/services sold	3,374.7	1,925.1	1,883.5
Operations and maintenance	136.0	158.1	190.2
General and administrative	96.5	88.2	116.3
Loss on long-lived assets, net	(65.6)	(65.6)	(821.2)
Goodwill impairment	(38.8)	(162.6)	(1,406.3)
Loss on contingent consideration	(57.0)	0.0	0.0
Earnings (loss) from unconsolidated affiliates, net	47.8	31.5	(60.8)
Other income, net	1.3	0.5	0.6
EBITDA	161.4	152.9	(1,844.9)
Goodwill	147.6	199.0
Assets	4,284.9	4,448.9
Payments to Acquire Property, Plant, and Equipment	188.4	100.7	182.7
CMLP
Segment Reporting Information [Line Items]
Operating revenues	3,880.9	2,520.5	2,632.8
Intersegment Revenues	0.0	0.0	0.0
Costs of product/services sold	3,374.7	1,925.1	1,883.5
Operations and maintenance	136.0	155.0	188.7
General and administrative	93.1	85.6	105.6
Loss on long-lived assets, net	(65.6)	(65.6)	(227.8)
Goodwill impairment	(38.8)	(162.6)	(1,149.1)
Loss on contingent consideration	(57.0)	0.0	0.0
Earnings (loss) from unconsolidated affiliates, net	47.8	31.5	(60.8)
Other income, net	0.8
EBITDA	164.3	158.1	(982.7)
Goodwill	147.6	199.0	1,085.5
Assets	4,466.3	4,640.6
Payments to Acquire Property, Plant, and Equipment	188.4	100.7	182.7
Gathering systems and pipelines and related assets
Segment Reporting Information [Line Items]
Operating revenues	1,688.2	1,118.8	1,381.0
Intersegment Revenues	134.5	108.6	66.7
Costs of product/services sold	1,480.8	917.0	1,103.9
Operations and maintenance	68.4	77.0	89.0
General and administrative	0.0	0.0	0.0
Loss on long-lived assets, net	(14.4)	(2.0)	(787.3)
Goodwill impairment	0.0	(8.6)	(329.7)
Loss on contingent consideration	0.0
Earnings (loss) from unconsolidated affiliates, net	18.9	20.3	(43.4)
Other income, net	0.8	0.0	0.0
EBITDA	278.8	243.1	(905.6)
Goodwill	45.9	45.9
Assets	2,474.1	2,359.7
Payments to Acquire Property, Plant, and Equipment	162.7	76.6	132.7
Gathering systems and pipelines and related assets \| CMLP
Segment Reporting Information [Line Items]
Operating revenues	1,688.2	1,118.8	1,381.0
Intersegment Revenues	134.5	108.6	66.7
Costs of product/services sold	1,480.8	917.0	1,103.9
Operations and maintenance	68.4	77.0	89.0
General and administrative	0.0	0.0	0.0
Loss on long-lived assets, net	(14.4)	(2.0)	(194.1)
Goodwill impairment	0.0	(8.6)	(72.5)
Loss on contingent consideration	0.0
Earnings (loss) from unconsolidated affiliates, net	18.9	20.3	(43.4)
Other income, net	0.8
EBITDA	278.8	243.1	(55.2)
Goodwill	45.9	45.9
Assets	2,662.0	2,561.9
Payments to Acquire Property, Plant, and Equipment	162.7	76.6	132.7
Storage and Transportation
Segment Reporting Information [Line Items]
Operating revenues	37.2	165.3	266.3
Intersegment Revenues	6.7	4.2	0.0
Costs of product/services sold	0.3	5.1	20.1
Operations and maintenance	4.2	21.4	31.7
General and administrative	0.0	0.0	0.0
Loss on long-lived assets, net	0.0	(32.2)	(1.6)
Goodwill impairment	0.0	(44.9)	(623.4)
Loss on contingent consideration	(57.0)
Earnings (loss) from unconsolidated affiliates, net	28.9	11.2	(17.4)
Other income, net	0.0	0.0	0.0
EBITDA	11.3	77.1	(427.9)
Goodwill	0.0	0.0
Assets	1,040.6	1,094.6
Payments to Acquire Property, Plant, and Equipment	1.3	3.3	26.4
Storage and Transportation \| CMLP
Segment Reporting Information [Line Items]
Operating revenues	37.2	165.3	266.3
Intersegment Revenues	6.7	4.2	0.0
Costs of product/services sold	0.3	5.1	20.1
Operations and maintenance	4.2	18.3	30.2
General and administrative	0.0	0.0	0.0
Loss on long-lived assets, net	0.0	(32.2)	(1.4)
Goodwill impairment	0.0	(44.9)	(623.4)
Loss on contingent consideration	(57.0)
Earnings (loss) from unconsolidated affiliates, net	28.9	11.2	(17.4)
Other income, net	0.0
EBITDA	11.3	80.2	(426.2)
Goodwill	0.0	0.0
Assets	1,040.6	1,094.6
Payments to Acquire Property, Plant, and Equipment	1.3	3.3	26.4
Marketing Supply and Logistics
Segment Reporting Information [Line Items]
Operating revenues	2,155.5	1,236.4	985.5
Intersegment Revenues	(141.2)	(112.8)	(66.7)
Costs of product/services sold	1,893.6	1,003.0	759.5
Operations and maintenance	63.4	59.7	69.5
General and administrative	0.0	0.0	0.0
Loss on long-lived assets, net	(48.2)	(31.4)	(32.3)
Goodwill impairment	(38.8)	(109.1)	(453.2)
Loss on contingent consideration	0.0
Earnings (loss) from unconsolidated affiliates, net	0.0	0.0	0.0
Other income, net	0.0	0.0	0.0
EBITDA	(29.7)	(79.6)	(395.7)
Goodwill	101.7	153.1
Assets	757.1	972.2
Payments to Acquire Property, Plant, and Equipment	17.7	19.1	22.8
Marketing Supply and Logistics \| CMLP
Segment Reporting Information [Line Items]
Operating revenues	2,155.5	1,236.4	985.5
Intersegment Revenues	(141.2)	(112.8)	(66.7)
Costs of product/services sold	1,893.6	1,003.0	759.5
Operations and maintenance	63.4	59.7	69.5
General and administrative	0.0	0.0	0.0
Loss on long-lived assets, net	(48.2)	(31.4)	(32.3)
Goodwill impairment	(38.8)	(109.1)	(453.2)
Loss on contingent consideration	0.0
Earnings (loss) from unconsolidated affiliates, net	0.0	0.0	0.0
Other income, net	0.0
EBITDA	(29.7)	(79.6)	(395.7)
Goodwill	101.7	153.1
Assets	757.1	972.2
Payments to Acquire Property, Plant, and Equipment	17.7	19.1	22.8
Corporate Segment
Segment Reporting Information [Line Items]
Operating revenues	0.0	0.0	0.0
Intersegment Revenues	0.0	0.0	0.0
Costs of product/services sold	0.0	0.0	0.0
Operations and maintenance	0.0	0.0	0.0
General and administrative	96.5	88.2	116.3
Loss on long-lived assets, net	(3.0)	0.0	0.0
Goodwill impairment	0.0	0.0	0.0
Loss on contingent consideration	0.0
Earnings (loss) from unconsolidated affiliates, net	0.0	0.0	0.0
Other income, net	0.5	0.5	0.6
EBITDA	(99.0)	(87.7)	(115.7)
Goodwill	0.0	0.0
Assets	13.1	22.4
Payments to Acquire Property, Plant, and Equipment	6.7	1.7	0.8
Corporate Segment \| CMLP
Segment Reporting Information [Line Items]
Operating revenues	0.0	0.0	0.0
Intersegment Revenues	0.0	0.0	0.0
Costs of product/services sold	0.0	0.0	0.0
Operations and maintenance	0.0	0.0	0.0
General and administrative	93.1	85.6	105.6
Loss on long-lived assets, net	(3.0)	0.0	0.0
Goodwill impairment	0.0	0.0	0.0
Loss on contingent consideration	0.0
Earnings (loss) from unconsolidated affiliates, net	0.0	0.0	0.0
Other income, net	0.0
EBITDA	(96.1)	(85.6)	(105.6)
Goodwill	0.0	0.0
Assets	6.6	11.9
Payments to Acquire Property, Plant, and Equipment	$ 6.7	$ 1.7	$ 0.8

Condensed Consolidating Financial Information (Balance Sheet) (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Current assets:
Cash	$ 1.3	$ 1.6	$ 0.5	$ 8.8
Accounts receivable	442.7	289.8
Inventory	68.4	66.0
Total current assets	530.5	373.4
Property, plant and equipment, net	1,820.8	2,097.6
Investments in unconsolidated affiliates	1,183.0	1,115.4
Other assets	5.8	6.1
Total assets	4,284.9	4,448.9
Current liabilities:
Accounts payable	349.4	217.2
Total current liabilities	505.1	337.3
Long-term liabilities:
Long-term debt, less current portion	1,491.3	1,522.7
Other long-term liabilities	104.7	44.6
Deferred income taxes	3.3	5.3
Total partners’ capital	2,180.5	2,539.0	2,946.9	5,584.5
Total liabilities and partners’ capital	4,284.9	4,448.9
Eliminations
Current assets:
Cash	0.0	0.0	0.0	0.0
Accounts receivable	0.0	0.0
Inventory	0.0	0.0
Other	0.0	0.0
Total current assets	0.0	0.0
Property, plant and equipment, net	0.0	0.0
Intangible Assets, Net (Including Goodwill)	0.0	0.0
Investments in consolidated affiliates	(3,705.4)	(4,093.7)
Investments in unconsolidated affiliates	0.0	0.0
Other assets	0.0	0.0
Total assets	(3,705.4)	(4,093.7)
Current liabilities:
Accounts payable	0.0	0.0
Total current liabilities	0.0	0.0
Total current liabilities	0.0	0.0
Long-term liabilities:
Long-term debt, less current portion	0.0	0.0
Other long-term liabilities	0.0	0.0
Deferred income taxes	0.0	0.0
Partners' capital	(3,705.4)	(4,093.7)
Interest of non-controlling partners in subsidiary	0.0	0.0
Total partners’ capital	(3,705.4)	(4,093.7)
Total liabilities and partners’ capital	(3,705.4)	(4,093.7)
Parent Company, Crestwood Midstream Partners, LP \| Reportable Legal Entities
Current assets:
Cash	1.0	1.3	0.1	0.0
Accounts receivable	0.0	0.0
Inventory	0.0	0.0
Other	0.0	0.0
Total current assets	1.0	1.3
Property, plant and equipment, net	0.0	0.0
Intangible Assets, Net (Including Goodwill)	0.0	0.0
Investments in consolidated affiliates	3,705.4	4,093.7
Investments in unconsolidated affiliates	0.0	0.0
Other assets	0.0	0.0
Total assets	3,706.4	4,095.0
Current liabilities:
Accounts payable	0.0	0.0
Total current liabilities	20.5	23.1
Total current liabilities	20.5	23.1
Long-term liabilities:
Long-term debt, less current portion	1,490.5	1,521.2
Other long-term liabilities	0.0	0.0
Deferred income taxes	0.0	0.0
Partners' capital	2,195.4	2,550.7
Interest of non-controlling partners in subsidiary	0.0	0.0
Total partners’ capital	2,195.4	2,550.7
Total liabilities and partners’ capital	3,706.4	4,095.0
Guarantor Subsidiaries \| Reportable Legal Entities
Current assets:
Cash	0.0	0.0	0.0	7.6
Accounts receivable	439.7	289.3
Inventory	68.4	66.0
Other	18.1	16.0
Total current assets	526.2	371.3
Property, plant and equipment, net	2,007.5	2,298.4
Intangible Assets, Net (Including Goodwill)	743.3	851.9
Investments in consolidated affiliates	0.0	0.0
Investments in unconsolidated affiliates	0.0	0.0
Other assets	2.4	1.8
Total assets	3,279.4	3,523.4
Current liabilities:
Accounts payable	346.8	214.5
Total current liabilities	134.0	94.4
Total current liabilities	480.8	308.9
Long-term liabilities:
Long-term debt, less current portion	0.8	1.5
Other long-term liabilities	45.6	42.0
Deferred income taxes	0.7	0.7
Partners' capital	2,751.5	3,170.3
Interest of non-controlling partners in subsidiary	0.0	0.0
Total partners’ capital	2,751.5	3,170.3
Total liabilities and partners’ capital	3,279.4	3,523.4
Non-Guarantor Subsidiaries \| Reportable Legal Entities
Current assets:
Cash	0.0	0.0	0.0	0.0
Accounts receivable	2.9	0.5
Inventory	0.0	0.0
Other	0.0	0.0
Total current assets	2.9	0.5
Property, plant and equipment, net	0.0	0.0
Intangible Assets, Net (Including Goodwill)	0.0	0.0
Investments in consolidated affiliates	0.0	0.0
Investments in unconsolidated affiliates	1,183.0	1,115.4
Other assets	0.0	0.0
Total assets	1,185.9	1,115.9
Current liabilities:
Accounts payable	0.0	0.0
Total current liabilities	0.0	0.0
Total current liabilities	0.0	0.0
Long-term liabilities:
Long-term debt, less current portion	0.0	0.0
Other long-term liabilities	57.0	0.0
Deferred income taxes	0.0	0.0
Partners' capital	953.9	923.4
Interest of non-controlling partners in subsidiary	175.0	192.5
Total partners’ capital	1,128.9	1,115.9
Total liabilities and partners’ capital	1,185.9	1,115.9
CMLP
Current assets:
Cash	1.0	1.3	$ 0.1	$ 7.6
Accounts receivable	442.6	289.8
Inventory	68.4	66.0
Other	18.1	16.0
Total current assets	530.1	373.1
Property, plant and equipment, net	2,007.5	2,298.4
Intangible Assets, Net (Including Goodwill)	743.3	851.9
Investments in consolidated affiliates	0.0	0.0
Investments in unconsolidated affiliates	1,183.0	1,115.4
Other assets	2.4	1.8
Total assets	4,466.3	4,640.6
Current liabilities:
Accounts payable	346.8	214.5
Total current liabilities	154.5	117.5
Total current liabilities	501.3	332.0
Long-term liabilities:
Long-term debt, less current portion	1,491.3	1,522.7
Other long-term liabilities	102.6	42.0
Deferred income taxes	0.7	0.7
Partners' capital	2,195.4	2,550.7
Interest of non-controlling partners in subsidiary	175.0	192.5
Total partners’ capital	2,370.4	2,743.2
Total liabilities and partners’ capital	$ 4,466.3	$ 4,640.6

Condensed Consolidating Financial Information (Statements Of Operations) (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenues:
Storage and transportation		$ 37.2	$ 165.3	$ 266.3
Related party (Note 16)		1.8	2.6	3.9
Revenues		3,880.9	2,520.5	2,632.8
Costs of product/services sold (exclusive of items shown separately below):
Product costs - related party (Note 16)		15.3	17.7	28.9
Total costs of products/services sold		3,374.7	1,925.1	1,883.5
Expenses:
Operations and maintenance		136.0	158.1	190.2
General and administrative		96.5	88.2	116.3
Depreciation, amortization and accretion		191.7	229.6	300.1
Loss on long-lived assets, net		(65.6)	(65.6)	(821.2)
Goodwill impairment		(38.8)	(162.6)	(1,406.3)
Loss on contingent consideration		(57.0)	0.0	0.0
Operating income (loss)		(79.4)	(108.7)	(2,084.8)
Other income (expense):
Earnings (loss) from unconsolidated affiliates, net		47.8	31.5	(60.8)
Interest and debt expense, net		(99.4)	(125.1)	(140.1)
Gain (loss) on modification/extinguishment of debt	$ 10.0	(37.7)	10.0	(20.0)
Other income, net		1.3	0.5	0.6
Loss before income taxes		(167.4)	(191.8)	(2,305.1)
(Provision) benefit for income taxes		0.8	(0.3)	1.4
Net loss		(166.6)	(192.1)	(2,303.7)
Net income attributable to non-controlling partners in subsidiary		25.3	24.2	(636.8)
Net income (loss) attributable to parent		(191.9)	(216.3)	(1,666.9)
Net income attributable to preferred units		62.5	28.7	6.2
Net income (loss) attributable to partners		(254.4)	(245.0)	(1,673.1)
Eliminations
Revenues:
Revenues		0.0	0.0	0.0
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold		0.0	0.0	0.0
Expenses:
Operations and maintenance		0.0	0.0	0.0
General and administrative		0.0	0.0	0.0
Depreciation, amortization and accretion		0.0	0.0	0.0
Costs and Expenses		0.0	0.0	0.0
Loss on long-lived assets, net		0.0	0.0	0.0
Goodwill impairment		0.0	0.0	0.0
Loss on contingent consideration		0.0
Operating income (loss)		0.0	0.0	0.0
Other income (expense):
Earnings (loss) from unconsolidated affiliates, net		0.0	0.0	0.0
Interest and debt expense, net		0.0	0.0	0.0
Gain (loss) on modification/extinguishment of debt		0.0	0.0	0.0
Other income, net		0.0
Loss from unconsolidated affiliates		(3.9)	40.2	1,219.0
Net loss		(3.9)	40.2	1,219.0
Net income attributable to non-controlling partners in subsidiary		0.0	0.0	0.0
Net income (loss) attributable to parent		(3.9)	40.2	1,219.0
Net income attributable to preferred units				0.0
Net income (loss) attributable to partners				1,219.0
Parent Company, Crestwood Midstream Partners, LP \| Reportable Legal Entities
Revenues:
Revenues		0.0	0.0	0.0
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold		0.0	0.0	0.0
Expenses:
Operations and maintenance		0.0	0.0	0.0
General and administrative		67.6	66.4	65.3
Depreciation, amortization and accretion		0.0	0.0	0.0
Costs and Expenses		67.6	66.4	65.3
Loss on long-lived assets, net		0.0	0.0	0.0
Goodwill impairment		0.0	0.0	0.0
Loss on contingent consideration		0.0
Operating income (loss)		(67.6)	(66.4)	(65.3)
Other income (expense):
Earnings (loss) from unconsolidated affiliates, net		0.0	0.0	0.0
Interest and debt expense, net		(99.4)	(125.1)	(130.5)
Gain (loss) on modification/extinguishment of debt		(37.7)	10.0	(18.9)
Other income, net		0.0
Loss from unconsolidated affiliates		3.9	(40.2)	(1,219.0)
Net loss		(200.8)	(221.7)	(1,433.7)
Net income attributable to non-controlling partners in subsidiary		0.0	0.0	0.0
Net income (loss) attributable to parent		(200.8)	(221.7)	(1,433.7)
Net income attributable to preferred units				23.1
Net income (loss) attributable to partners				(1,456.8)
Guarantor Subsidiaries \| Reportable Legal Entities
Revenues:
Revenues		3,880.9	2,520.5	2,632.8
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold		3,374.7	1,925.1	1,883.5
Expenses:
Operations and maintenance		136.0	155.0	188.7
General and administrative		25.5	19.2	40.3
Depreciation, amortization and accretion		202.7	240.5	278.5
Costs and Expenses		364.2	414.7	507.5
Loss on long-lived assets, net		(65.6)	(65.6)	(227.8)
Goodwill impairment		(38.8)	(162.6)	(1,149.1)
Loss on contingent consideration		0.0
Operating income (loss)		37.6	(47.5)	(1,135.1)
Other income (expense):
Earnings (loss) from unconsolidated affiliates, net		0.0	0.0	0.0
Interest and debt expense, net		0.0	0.0	0.0
Gain (loss) on modification/extinguishment of debt		0.0	0.0	0.0
Other income, net		0.8
Loss from unconsolidated affiliates		0.0	0.0	0.0
Net loss		38.4	(47.5)	(1,135.1)
Net income attributable to non-controlling partners in subsidiary		0.0	0.0	0.0
Net income (loss) attributable to parent		38.4	(47.5)	(1,135.1)
Net income attributable to preferred units				0.0
Net income (loss) attributable to partners				(1,135.1)
Non-Guarantor Subsidiaries \| Reportable Legal Entities
Revenues:
Revenues		0.0	0.0	0.0
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold		0.0	0.0	0.0
Expenses:
Operations and maintenance		0.0	0.0	0.0
General and administrative		0.0	0.0	0.0
Depreciation, amortization and accretion		0.0	0.0	0.0
Costs and Expenses		0.0	0.0	0.0
Loss on long-lived assets, net		0.0	0.0	0.0
Goodwill impairment		0.0	0.0	0.0
Loss on contingent consideration		(57.0)
Operating income (loss)		(57.0)	0.0	0.0
Other income (expense):
Earnings (loss) from unconsolidated affiliates, net		47.8	31.5	(60.8)
Interest and debt expense, net		0.0	0.0	0.0
Gain (loss) on modification/extinguishment of debt		0.0	0.0	0.0
Other income, net		0.0
Loss from unconsolidated affiliates		0.0	0.0	0.0
Net loss		(9.2)	31.5	(60.8)
Net income attributable to non-controlling partners in subsidiary		25.3	24.2	23.1
Net income (loss) attributable to parent		(34.5)	7.3	(83.9)
Net income attributable to preferred units				0.0
Net income (loss) attributable to partners				(83.9)
CMLP
Revenues:
Revenues		3,880.9	2,520.5	2,632.8
Costs of product/services sold (exclusive of items shown separately below):
Total costs of products/services sold		3,374.7	1,925.1	1,883.5
Expenses:
Operations and maintenance		136.0	155.0	188.7
General and administrative		93.1	85.6	105.6
Depreciation, amortization and accretion		202.7	240.5	278.5
Costs and Expenses		431.8	481.1	572.8
Loss on long-lived assets, net		(65.6)	(65.6)	(227.8)
Goodwill impairment		(38.8)	(162.6)	(1,149.1)
Loss on contingent consideration		(57.0)
Operating income (loss)		(87.0)	(113.9)	(1,200.4)
Other income (expense):
Earnings (loss) from unconsolidated affiliates, net		47.8	31.5	(60.8)
Interest and debt expense, net		(99.4)	(125.1)	(130.5)
Gain (loss) on modification/extinguishment of debt		(37.7)	10.0	(18.9)
Other income, net		0.8
Loss from unconsolidated affiliates		0.0	0.0	0.0
Net loss		(175.5)	(197.5)	(1,410.6)
Net income attributable to non-controlling partners in subsidiary		25.3	24.2	23.1
Net income (loss) attributable to parent		$ (200.8)	$ (221.7)	(1,433.7)
Net income attributable to preferred units				23.1
Net income (loss) attributable to partners				$ (1,456.8)

Condensed Consolidating Financial Information (Statements Of Cash Flows) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash flows from operating activities		$ 255.9	$ 346.1	$ 440.7
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired		0.0	7.2	0.0
Purchases of property, plant and equipment		(188.4)	(100.7)	(182.7)
Investment in unconsolidated affiliates		(58.0)	(12.4)	(42.0)
Net proceeds from sale of assets		225.2	972.7	2.7
Capital distributions from unconsolidated affiliates		59.9	14.8	9.3
Net cash provided by (used in) investing activities		38.7	867.2	(212.7)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		2,838.6	1,565.3	4,261.8
Payments on long-term debt		(2,913.9)	(2,536.3)	(4,113.0)
Payments on capital leases		(2.7)	(1.9)	(2.2)
Payments for debt-related deferred costs		(1.0)	(3.5)	(17.3)
Payments for Repurchase of Redeemable Noncontrolling Interest	$ (202.7)	(202.7)	0.0	0.0
Financing fees paid for early debt redemption		0.0	0.0	(13.6)
Distributions to partners		(167.6)	(219.8)	(171.5)
Net proceeds from issuance of preferred equity of subsidiary	(175.0)	(175.0)	0.0	0.0
Taxes paid for unit-based compensation vesting		(5.5)	(0.8)	(3.8)
Other		(0.1)	0.0	(1.3)
Net cash used in financing activities		(294.9)	(1,212.2)	(236.3)
Net change in cash		(0.3)	1.1	(8.3)
Cash at beginning of period		1.6	0.5	8.8
Cash at end of period	1.3	1.3	1.6	0.5
Eliminations
Cash flows from operating activities		0.0	0.0	0.0
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired			0.0
Purchases of property, plant and equipment		0.0	0.0	0.0
Investment in unconsolidated affiliates		0.0	0.0	0.0
Net proceeds from sale of assets		0.0	0.0	0.0
Capital distributions from unconsolidated affiliates		0.0	0.0	0.0
Contributions to (Distributions from) Consolidated Affiliates		(4.3)	(26.2)	31.2
Net cash provided by (used in) investing activities		(4.3)	(26.2)	31.2
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		0.0	0.0	0.0
Payments on long-term debt		0.0	0.0	0.0
Payments on capital leases		0.0	0.0	0.0
Payments for debt-related deferred costs		0.0	0.0	0.0
Payments for Repurchase of Redeemable Noncontrolling Interest		0.0
Financing fees paid for early debt redemption				0.0
Distributions to partners		0.0	0.0	0.0
Contributions from (Distributions to) Parent		4.3	26.2	(31.2)
Net proceeds from issuance of preferred equity of subsidiary		0.0
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units				0.0
Taxes paid for unit-based compensation vesting		0.0	0.0	0.0
Change in intercompany balances		0.0	0.0	0.0
Other		0.0		0.0
Net cash used in financing activities		4.3	26.2	(31.2)
Net change in cash		0.0	0.0	0.0
Cash at beginning of period		0.0	0.0	0.0
Cash at end of period	0.0	0.0	0.0	0.0
Parent Company, Crestwood Midstream Partners, LP \| Reportable Legal Entities
Cash flows from operating activities		(162.3)	(188.0)	(190.8)
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired			0.0
Purchases of property, plant and equipment		(6.7)	(1.7)	(0.8)
Investment in unconsolidated affiliates		0.0	0.0	0.0
Net proceeds from sale of assets		0.0	0.0	0.0
Capital distributions from unconsolidated affiliates		0.0	0.0	0.0
Contributions to (Distributions from) Consolidated Affiliates		4.3	26.2	(31.2)
Net cash provided by (used in) investing activities		(2.4)	24.5	(32.0)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		2,838.6	1,565.3	3,490.1
Payments on long-term debt		(2,912.6)	(2,535.3)	(2,960.9)
Payments on capital leases		0.0	0.0	0.0
Payments for debt-related deferred costs		(1.0)	(3.5)	(17.3)
Payments for Repurchase of Redeemable Noncontrolling Interest		0.0
Financing fees paid for early debt redemption				(13.6)
Distributions to partners		(174.0)	(227.6)	(808.2)
Contributions from (Distributions to) Parent		0.0	0.0	0.0
Net proceeds from issuance of preferred equity of subsidiary		0.0
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units				(58.8)
Taxes paid for unit-based compensation vesting		0.0	0.0	0.0
Change in intercompany balances		413.4	1,365.8	474.1
Other		0.0		(0.1)
Net cash used in financing activities		164.4	164.7	222.9
Net change in cash		(0.3)	1.2	0.1
Cash at beginning of period		1.3	0.1	0.0
Cash at end of period	1.0	1.0	1.3	0.1
CMLP
Cash flows from operating activities		262.2	353.8	471.8
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired			7.2
Purchases of property, plant and equipment		(188.4)	(100.7)	(182.7)
Investment in unconsolidated affiliates		(58.0)	(12.4)	(41.8)
Net proceeds from sale of assets		225.2	972.7	2.7
Capital distributions from unconsolidated affiliates		59.9	14.8	9.3
Contributions to (Distributions from) Consolidated Affiliates		0.0	0.0	0.0
Net cash provided by (used in) investing activities		38.7	867.2	(212.5)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		2,838.6	1,565.3	3,490.1
Payments on long-term debt		(2,913.9)	(2,536.1)	(2,960.9)
Payments on capital leases		(2.7)	(1.9)	(2.2)
Payments for debt-related deferred costs		(1.0)	(3.5)	(17.3)
Payments for Repurchase of Redeemable Noncontrolling Interest		(202.7)
Financing fees paid for early debt redemption				(13.6)
Distributions to partners		(189.2)	(242.8)	(819.5)
Contributions from (Distributions to) Parent		0.0	0.0	0.0
Net proceeds from issuance of preferred equity of subsidiary		(175.0)
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units				(58.8)
Taxes paid for unit-based compensation vesting		(5.5)	(0.8)	(2.1)
Change in intercompany balances		0.0	0.0	0.0
Other		0.2		(0.1)
Net cash used in financing activities		(301.2)	(1,219.8)	(266.8)
Net change in cash		(0.3)	1.2	(7.5)
Cash at beginning of period		1.3	0.1	7.6
Cash at end of period	1.0	1.0	1.3	0.1
Non-Guarantor Subsidiaries \| Reportable Legal Entities
Cash flows from operating activities		45.3	39.0	12.6
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired			0.0
Purchases of property, plant and equipment		0.0	0.0	0.0
Investment in unconsolidated affiliates		(58.0)	(12.4)	(41.8)
Net proceeds from sale of assets		0.0	0.0	0.0
Capital distributions from unconsolidated affiliates		59.9	14.8	9.3
Contributions to (Distributions from) Consolidated Affiliates		0.0	0.0	0.0
Net cash provided by (used in) investing activities		1.9	2.4	(32.5)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		0.0	0.0	0.0
Payments on long-term debt		0.0	0.0	0.0
Payments on capital leases		0.0	0.0	0.0
Payments for debt-related deferred costs		0.0	0.0	0.0
Payments for Repurchase of Redeemable Noncontrolling Interest		(202.7)
Financing fees paid for early debt redemption				0.0
Distributions to partners		(15.2)	(15.2)	(11.3)
Contributions from (Distributions to) Parent		(4.3)	(26.2)	31.2
Net proceeds from issuance of preferred equity of subsidiary		(175.0)
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units				0.0
Taxes paid for unit-based compensation vesting		0.0	0.0	0.0
Change in intercompany balances		0.0	0.0	0.0
Other		0.0		0.0
Net cash used in financing activities		(47.2)	(41.4)	19.9
Net change in cash		0.0	0.0	0.0
Cash at beginning of period		0.0	0.0	0.0
Cash at end of period	0.0	0.0	0.0	0.0
Guarantor Subsidiaries \| Reportable Legal Entities
Cash flows from operating activities		379.2	502.8	650.0
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired			7.2
Purchases of property, plant and equipment		(181.7)	(99.0)	(181.9)
Investment in unconsolidated affiliates		0.0	0.0	0.0
Net proceeds from sale of assets		225.2	972.7	2.7
Capital distributions from unconsolidated affiliates		0.0	0.0	0.0
Contributions to (Distributions from) Consolidated Affiliates		0.0	0.0	0.0
Net cash provided by (used in) investing activities		43.5	866.5	(179.2)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		0.0	0.0	0.0
Payments on long-term debt		(1.3)	(0.8)	0.0
Payments on capital leases		(2.7)	(1.9)	(2.2)
Payments for debt-related deferred costs		0.0	0.0	0.0
Payments for Repurchase of Redeemable Noncontrolling Interest		0.0
Financing fees paid for early debt redemption				0.0
Distributions to partners		0.0	0.0	0.0
Contributions from (Distributions to) Parent		0.0	0.0	0.0
Net proceeds from issuance of preferred equity of subsidiary		0.0
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units				0.0
Taxes paid for unit-based compensation vesting		(5.5)	(0.8)	(2.1)
Change in intercompany balances		(413.4)	(1,365.8)	(474.1)
Other		0.2		0.0
Net cash used in financing activities		(422.7)	(1,369.3)	(478.4)
Net change in cash		0.0	0.0	(7.6)
Cash at beginning of period		0.0	0.0	7.6
Cash at end of period	0.0	0.0	0.0	0.0
CMLP
Cash flows from operating activities		262.2	353.8	471.8
Cash flows from investing activities:
Payments to Acquire Businesses, Net of Cash Acquired		0.0	7.2	0.0
Purchases of property, plant and equipment		(188.4)	(100.7)	(182.7)
Investment in unconsolidated affiliates		(58.0)	(12.4)	(41.8)
Net proceeds from sale of assets		225.2	972.7	2.7
Capital distributions from unconsolidated affiliates		59.9	14.8	9.3
Net cash provided by (used in) investing activities		38.7	867.2	(212.5)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		2,838.6	1,565.3	3,490.1
Payments on long-term debt		(2,913.9)	(2,536.1)	(2,960.9)
Payments on capital leases		(2.7)	(1.9)	(2.2)
Payments for debt-related deferred costs		(1.0)	(3.5)	(17.3)
Payments for Repurchase of Redeemable Noncontrolling Interest		(202.7)	0.0
Financing fees paid for early debt redemption		0.0	0.0	(13.6)
Distributions to partners		(189.2)	(242.8)	(819.5)
Net proceeds from issuance of preferred equity of subsidiary		(175.0)	0.0	0.0
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units		0.0	0.0	(58.8)
Taxes paid for unit-based compensation vesting		(5.5)	(0.8)	(2.1)
Other		0.2	0.0	(0.1)
Net cash used in financing activities		(301.2)	(1,219.8)	(266.8)
Net change in cash		(0.3)	1.2	(7.5)
Cash at beginning of period		1.3	0.1	7.6
Cash at end of period	$ 1.0	$ 1.0	$ 1.3	$ 0.1

Schedule I - Crestwood Equity Partners LP - Parent Only - Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Cash	$ 1.3	$ 1.6	$ 0.5	$ 8.8
Total current assets	530.5	373.4
Property, plant and equipment, net	1,820.8	2,097.6
Total assets	4,284.9	4,448.9
Accrued expenses	105.9	90.5
Current portion of long-term debt	0.9	1.0
Total current liabilities	505.1	337.3
Long-term debt, less current portion	1,491.3	1,522.7
Other long-term liabilities	104.7	44.6
Total partners’ capital	2,180.5	2,539.0	2,946.9	5,584.5
Total liabilities and partners’ capital	4,284.9	4,448.9
Parent Company
Condensed Financial Statements, Captions [Line Items]
Cash	0.3	0.3	$ 0.4	$ 3.7
Total current assets	0.3	0.3
Property, plant and equipment, net	1.2	1.4
Intangible assets, net	1.4	4.5
Investments in subsidiaries	2,005.1	2,342.7
Other assets	3.5	4.3
Total assets	2,011.5	2,353.2
Accounts payable	2.7	2.7
Accrued expenses	1.2	1.4
Total current liabilities	3.9	4.1
Other long-term liabilities	2.1	2.6
Total partners’ capital	2,005.5	2,346.5
Total liabilities and partners’ capital	$ 2,011.5	$ 2,353.2

Schedule I - Crestwood Equity Partners LP - Parent Only - Statement of Operations (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Revenues		$ 3,880.9	$ 2,520.5	$ 2,632.8
Operating income (loss)		(79.4)	(108.7)	(2,084.8)
Interest and debt expense, net		(99.4)	(125.1)	(140.1)
Gain (loss) on modification/extinguishment of debt	$ 10.0	(37.7)	10.0	(20.0)
Other income, net		1.3	0.5	0.6
Loss before income taxes		(167.4)	(191.8)	(2,305.1)
(Provision) benefit for income taxes		0.8	(0.3)	1.4
Net loss		(166.6)	(192.1)	(2,303.7)
Net income attributable to non-controlling partners in subsidiary		25.3	24.2	(636.8)
Net income (loss) attributable to parent		(191.9)	(216.3)	(1,666.9)
Parent Company
Condensed Financial Statements, Captions [Line Items]
Revenues		0.0	0.0	0.0
Costs and Expenses		6.7	6.0	14.5
Operating income (loss)		(6.7)	(6.0)	(14.5)
Interest and debt expense, net		0.0	0.0	(9.6)
Loss from unconsolidated affiliates		(160.4)	(186.6)	(2,279.1)
Gain (loss) on modification/extinguishment of debt		0.0	0.0	(1.1)
Other income, net		0.5	0.5	0.6
Net loss		(166.6)	(192.1)	(2,303.7)
Net income attributable to non-controlling partners in subsidiary		25.3	24.2	(636.8)
Net income (loss) attributable to parent		$ (191.9)	$ (216.3)	$ (1,666.9)

Schedule I - Crestwood Equity Partners LP - Parent Only - Statement of Comprehensive Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Net loss	$ (166.6)	$ (192.1)	$ (2,303.7)
Change in fair value of Suburban Propane Partners, LP units	(0.8)	0.8	(2.7)
Comprehensive loss	(167.4)	(191.3)	(2,306.4)
Comprehensive income (loss) attributable to non-controlling partners	(25.3)	(24.2)	636.8
Comprehensive loss attributable to Crestwood Equity Partners LP	(192.7)	(215.5)	(1,669.6)
Parent Company
Condensed Financial Statements, Captions [Line Items]
Net loss	(166.6)	(192.1)	(2,303.7)
Change in fair value of Suburban Propane Partners, LP units	(0.8)	0.8	(2.7)
Comprehensive loss	(167.4)	(191.3)	(2,306.4)
Comprehensive income (loss) attributable to non-controlling partners	(25.3)	(24.2)	636.8
Comprehensive loss attributable to Crestwood Equity Partners LP	$ (192.7)	$ (215.5)	$ (1,669.6)

Schedule I - Crestwood Equity Partners LP - Parent Only - Condensed Statement of Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	$ 255.9	$ 346.1	$ 440.7
Cash flows from investing activities	38.7	867.2	(212.7)
Proceeds from the issuance of long-term debt	2,838.6	1,565.3	4,261.8
Payments on long-term debt	(2,913.9)	(2,536.3)	(4,113.0)
Payments for debt-related deferred costs	(1.0)	(3.5)	(17.3)
Distributions to partners	(167.6)	(219.8)	(171.5)
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(15.0)	0.0	0.0
Net cash provided by (used in) financing activities	(294.9)	(1,212.2)	(236.3)
Net change in cash	(0.3)	1.1	(8.3)
Cash at beginning of period	1.6	0.5	8.8
Cash at end of period	1.3	1.6	0.5
Parent Company
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	(3.6)	(3.5)	(14.7)
Cash flows from investing activities	174.0	227.6	593.8
Proceeds from the issuance of long-term debt	0.0	0.0	771.7
Payments on long-term debt	0.0	(0.2)	(1,152.1)
Distributions to partners	(182.6)	(219.8)	(171.5)
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	15.2	0.0	0.0
Change in intercompany balances	(3.0)	(4.2)	(30.5)
Net cash provided by (used in) financing activities	(170.4)	(224.2)	(582.4)
Net change in cash	0.0	(0.1)	(3.3)
Cash at beginning of period	0.3	0.4	3.7
Cash at end of period	$ 0.3	$ 0.3	$ 0.4

Schedule I - Crestwood Equity Partners LP - Parent Only - Distributions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Parent Company
Dividends received from CMLP	$ 174.0	$ 227.6	$ 31.4

Schedule II - Crestwood Equity Partners LP - Valuation and Qualifying Accounts (Details) - Allowance for Doubtful Accounts - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Movement in Valuation Allowances and Reserves [Roll Forward]
Valuation Allowances and Reserves, Balance	$ 1.9	$ 0.4	$ 0.1
Valuation Allowances and Reserves, Charged to Cost and Expense	1.5	1.9	0.0
Valuation Allowances and Reserves, Charged to Other Accounts	0.0	0.0	0.4
Valuation Allowances and Reserves, Deductions	(1.0)	(0.4)	(0.1)
Valuation Allowances and Reserves, Balance	$ 2.4	$ 1.9	$ 0.4