Crestwood Gas Services Operating GP S-4/A 9 Jun 16 Registration of securities issued in business combination transactions (amended) Financial data

Document and Entity Information

Document and Entity Information	3 Months Ended
	Mar. 31, 2016
Document Information [Line Items]
Document Type	S-4/A
Amendment Flag	false
Document Period End Date	Mar. 31, 2016
Trading Symbol	CMLP
Entity Registrant Name	Crestwood Midstream Partners LP
Entity Central Index Key	1,304,464
Entity Filer Category	Accelerated Filer
Crestwood Equity Partners LP
Document Information [Line Items]
Document Type	S-4/A
Amendment Flag	false
Document Period End Date	Mar. 31, 2016
Entity Registrant Name	Crestwood Equity Partners LP
Entity Central Index Key	1,136,352
Entity Filer Category	Accelerated Filer

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Assets
Cash	$ 0.8	$ 0.1	$ 7.6
Accounts receivable	209.6	236.5	379.3
Inventory	26.6	44.5	46.6
Assets from price risk management activities	14.4	32.6	79.8
Prepaid expenses and other current assets	18.9	19.9	23.3
Total current assets	270.3	333.6	536.6
Property, plant and equipment	4,095.7	4,077.7	4,144.6
Less: accumulated depreciation and depletion	581.3	552	398.6
Property, plant and equipment, net	3,514.4	3,525.7	3,746
Intangible assets	959.3	959.3	1,123.7
Less: accumulated amortization	216	197.9	154.1
Intangible assets, net	743.3	761.4	969.6
Goodwill	975.8	1,085.5	2,234.6
Investment in unconsolidated affiliates	260.6	254.3	295.1
Other assets	3	3.1	3.3
Total assets	5,767.4	5,963.6	7,785.2
Current liabilities:
Accounts payable	116.5	141.4	235
Accrued expenses and other liabilities	94.6	103.3	150.1
Liabilities from price risk management activities	7.3	7.4	25.4
Current portion of long-term debt	0.9	0.9	0.8
Total current liabilities	219.3	253	411.3
Long-term debt, less current portion	2,530.8	2,501.8	2,014.5
Other long-term liabilities	44.1	43.3	38.3
Deferred income taxes	$ 0.6	$ 0.4	$ 0.7
Commitments and contingencies
Partners' capital
Crestwood Equity Partners LP partners' capital		$ 2,981.6	$ 4,701
Preferred units		0	447.7
Total company partners' capital	$ 2,787	2,981.6	5,148.7
Interest of non-controlling partners in subsidiaries	185.6	183.5	171.7
Total partners' capital	2,972.6	3,165.1	5,320.4
Total liabilities and partners' capital	5,767.4	5,963.6	7,785.2
Scenario, Previously Reported
Assets
Intangible assets		1,022.6
Less: accumulated amortization		220.3
Intangible assets, net		802.3
Total assets		6,004.5
Current liabilities:
Long-term debt, less current portion		2,542.7
Partners' capital
Total liabilities and partners' capital		6,004.5
Crestwood Equity Partners LP
Assets
Cash	1.1	0.5	8.8
Accounts receivable	209.6	236.5	379.6
Inventory	26.6	44.5	46.6
Assets from price risk management activities	14.4	32.6	79.8
Prepaid expenses and other current assets	20.7	21.7	23.3
Total current assets	272.4	335.8	538.1
Property, plant and equipment	3,765.7	3,747.7	4,273.9
Less: accumulated depreciation and depletion	462.7	436.9	380.1
Property, plant and equipment, net	3,303	3,310.8	3,893.8
Intangible assets	975.8	975.8	1,441.9
Less: accumulated amortization	225.6	206.6	210.6
Intangible assets, net	750.2	769.2	1,231.3
Goodwill	975.8	1,085.5	2,491.8
Investment in unconsolidated affiliates	260.6	254.3	295.1
Other assets	8	7.2	11.3
Total assets	5,570	5,762.8	8,461.4
Current liabilities:
Accounts payable	119.1	144.1	241.2
Accrued expenses and other liabilities	96.8	105.6	154.6
Liabilities from price risk management activities	7.3	7.4	25.4
Current portion of long-term debt	0.9	1.1	3.7
Total current liabilities	224.1	258.2	424.9
Long-term debt, less current portion	2,530.8	2,501.8	2,392.8
Other long-term liabilities	48.2	47.5	47.2
Deferred income taxes	$ 8.3	$ 8.4	$ 12
Commitments and contingencies
Partners' capital
Crestwood Equity Partners LP partners' capital	$ 2,035.6	$ 2,227.6	$ 776.2
Preferred units	537.4	535.8	0
Total company partners' capital	2,573	2,763.4	776.2
Interest of non-controlling partners in subsidiaries	185.6	183.5	4,808.3
Total partners' capital	2,758.6	2,946.9	5,584.5
Total liabilities and partners' capital	$ 5,570	5,762.8	$ 8,461.4
Crestwood Equity Partners LP | Scenario, Previously Reported
Assets
Intangible assets		1,039.1
Less: accumulated amortization		229
Intangible assets, net		810.1
Total assets		5,803.7
Current liabilities:
Long-term debt, less current portion		2,542.7
Partners' capital
Total liabilities and partners' capital		$ 5,803.7

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Allowance for doubtful accounts		$ 0.4	$ 0.1
Common units, issued		0	187,965,105
Common units, outstanding		0	187,965,105
Preferred units, issued		0	17,917,870
Preferred units, outstanding		0	17,917,870
Crestwood Equity Partners LP
Allowance for doubtful accounts		$ 0.4	$ 0.1
Limited Partners' Capital Account, Units Issued	69,478,525	68,555,305
Common units, issued		68,555,305	18,640,367
Limited Partners' Capital Account, Units Outstanding	69,478,525	68,555,305
Common units, outstanding		68,555,305	18,640,367
Preferred units, issued	62,122,562	60,718,245	0
Preferred units, outstanding	62,122,562	60,718,245	0

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenues:
Gathering and processing	$ 162.5	$ 260.9	$ 1,051.2	$ 1,831.5	$ 273.6
Marketing, supply and logistics	206.5	277.2	857.5	1,339.4	714.9
Total product revenue	369	538.1	1,908.7	3,170.9	988.5
Gathering and processing	75.7	88.4	325.9	332.2	161.5
Storage and transportation	59.4	67.6	266.3	250.8	116.8
Marketing, supply and logistics	31.2	36.4	128	160.6	70.9
Related party	0.7	1	3.9	3	74.9
Total services revenues	167	193.4	724.1	746.6	424.1
Total revenues	536	731.5	2,632.8	3,917.5	1,412.6
Costs of product/services sold (exclusive of items shown separately below):
Gathering and processing	175.4	258.2	1,074.4	1,816.9	234.5
Marketing, supply and logistics	166	242.2	705.6	1,196.1	681.7
Related party	4.3	8.3	28.9	42.2	32.5
Total product costs	345.7	508.7	1,808.9	3,055.2	948.7
Gathering and processing	0.1	0.2	0.6	0.8	0.4
Storage and transportation	2.9	5.3	20.1	22.8	12.8
Marketing, supply and logistics	14.7	15.5	53.9	76	33.5
Total service costs	17.7	21	74.6	99.6	46.7
Total costs of product/services sold	363.4	529.7	1,883.5	3,154.8	995.4
Expenses:
Operations and maintenance	41.7	50.6	188.7	195.4	103.4
General and administrative	22.2	25.6	105.6	91.7	84.1
Depreciation, amortization and accretion	64.9	68.8	278.5	255.4	139.4
Total Expenses	128.8	145	572.8	542.5	326.9
Gain (loss) on long-lived assets, net	0	(0.8)	227.8	35.1	(5.3)
Goodwill impairment	(109.7)	0	(1,149.1)	(48.8)	(4.1)
Loss on contingent consideration			0	(8.6)	(31.4)
Operating income (loss)	(65.9)	56	(1,200.4)	127.7	60.1
Earnings from unconsolidated affiliates, net	6.5	3.4	(60.8)	(0.7)	(0.1)
Interest and debt expense, net	(36.1)	(29.9)	(130.5)	(111.4)	(71.7)
Loss on modification/extinguishment of debt			(18.9)	0	0
Income (loss) before income taxes	(95.5)	29.5	(1,410.6)	15.6	(11.7)
Provision (benefit) for income taxes	(0.2)	0.4	0	0.9	0.7
Net income (loss)	(95.3)	29.1	(1,410.6)	14.7	(12.4)
Net income attributable to non-controlling partners	5.9	5.6	23.1	16.8	4.9
Net income (loss) attributable to Crestwood Equity Partners LP	(101.2)	23.5	(1,433.7)	(2.1)	(17.3)
Net income attributable to Class A preferred units	0	9.2	23.1	17.2	0
Net income (loss) attributable to partners	(101.2)	14.3	(1,456.8)	(19.3)	(17.3)
Crestwood Equity Partners LP
Revenues:
Gathering and processing	162.5	260.9	1,051.2	1,831.5	273.6
Marketing, supply and logistics	206.5	277.2	857.5	1,339.4	714.9
Total product revenue	369	538.1	1,908.7	3,170.9	988.5
Gathering and processing	75.7	88.4	325.9	332.2	161.5
Storage and transportation	59.4	67.6	266.3	264.6	130.9
Marketing, supply and logistics	31.2	36.4	128	160.6	70.9
Related party	0.7	1	3.9	3	74.9
Total services revenues	167	193.4	724.1	760.4	438.2
Total revenues	536	731.5	2,632.8	3,931.3	1,426.7
Costs of product/services sold (exclusive of items shown separately below):
Gathering and processing	175.4	258.2	1,074.4	1,816.9	234.5
Marketing, supply and logistics	166	242.2	705.6	1,196.1	681.7
Related party	4.3	8.3	28.9	42.2	32.5
Total product costs	345.7	508.7	1,808.9	3,055.2	948.7
Gathering and processing	0.1	0.2	0.6	0.8	0.4
Storage and transportation	2.9	5.3	20.1	33.3	19.7
Marketing, supply and logistics	14.7	15.5	53.9	76	33.5
Total service costs	17.7	21	74.6	110.1	53.6
Total costs of product/services sold	363.4	529.7	1,883.5	3,165.3	1,002.3
Expenses:
Operations and maintenance	41.8	50.6	190.2	203.3	104.6
General and administrative	23	27.5	116.3	100.2	93.5
Depreciation, amortization and accretion	62.3	74.2	300.1	285.3	167.9
Total Expenses	127.1	152.3	606.6	588.8	366
Gain (loss) on long-lived assets, net	0	(1)	821.2	1.9	(5.3)
Goodwill impairment	(109.7)	0	(1,406.3)	(48.8)	(4.1)
Loss on contingent consideration				(8.6)	(31.4)
Operating income (loss)	(64.2)	48.5	(2,084.8)	117.9	28.2
Earnings from unconsolidated affiliates, net	6.5	3.4	(60.8)	(0.7)	(0.1)
Interest and debt expense, net	(36.1)	(33.6)	(140.1)	(127.1)	(77.9)
Loss on modification/extinguishment of debt			(20)	0	0
Other income, net	0.1	0.2	0.6	0.6	0.2
Income (loss) before income taxes	(93.7)	18.5	(2,305.1)	(9.3)	(49.6)
Provision (benefit) for income taxes	0	0.4	(1.4)	1.1	1
Net income (loss)	(93.7)	18.1	(2,303.7)	(10.4)	(50.6)
Net income attributable to non-controlling partners	5.9	9.8	(636.8)	(66.8)	(57.3)
Net income (loss) attributable to Crestwood Equity Partners LP	(99.6)	8.3	(1,666.9)	56.4	6.7
Net income attributable to Class A preferred units	1.6	0	6.2	0	0
Net income (loss) attributable to partners	(101.2)	8.3	(1,673.1)	56.4	6.7
Subordinated unitholders' interest in net income	0	0.2	0	1.3	0.3
Common unitholders' interest in net income (loss)	$ (101.2)	$ 8.1	$ (1,673.1)	$ 55.1	$ 6.4
Net income (loss) per limited partner unit:
Basic	$ (1.47)	$ 0.44	$ (54)	$ 3.03	$ 0.59
Diluted	$ (1.47)	$ 0.44	$ (54)	$ 3.03	$ 0.59
Weighted-average limited partners' units
Basic	68,912	18,280	30,983	18,201	10,914
Dilutive units	0	439	0	439	439
Diluted	68,912	18,719	30,983	18,640	11,353

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Net income (loss)	$ (95.3)	$ 29.1	$ (1,410.6)	$ 14.7	$ (12.4)
Crestwood Equity Partners LP
Net income (loss)	(93.7)	18.1	(2,303.7)	(10.4)	(50.6)
Change in fair value of Suburban Propane Partners, L.P. units	0.8	0	(2.7)	(0.5)	(0.1)
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(92.9)	18.1	(2,306.4)	(10.9)	(50.7)
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	5.9	9.8	636.8	66.8	57.3
Comprehensive income (loss) attributable to Crestwood Equity Partners LP	$ (98.8)	$ 8.3	$ (1,669.6)	$ 55.9	$ 6.6

Consolidated Statement of Partn

Consolidated Statement of Partners' Capital - USD ($) $ in Millions	Total	Arrow Midstream Holdings, LLC	Crestwood Equity Partners LP	Crestwood Equity Partners LPArrow Midstream Holdings, LLC	Crestwood Equity Partners LPClass D Units	Crestwood Equity Partners LPClass C Units	Crestwood Equity Partners LPCommon Units	Crestwood Equity Partners LPSubordinated Units	Crestwood Equity Partners LPPreferred Units, Class A	Preferred Units	Preferred UnitsArrow Midstream Holdings, LLC	Preferred UnitsCrestwood Equity Partners LP	Preferred UnitsCrestwood Equity Partners LPArrow Midstream Holdings, LLC	Preferred UnitsCrestwood Equity Partners LPCrestwood Marcellus Midstream LLC	Preferred UnitsCrestwood Equity Partners LPClass D Units	Preferred UnitsCrestwood Equity Partners LPClass C Units	Common Unit Capital	Common Unit CapitalArrow Midstream Holdings, LLC	Common Unit CapitalCrestwood Equity Partners LP	Common Unit CapitalCrestwood Equity Partners LPArrow Midstream Holdings, LLC	Common Unit CapitalCrestwood Equity Partners LPCrestwood Marcellus Midstream LLC	Common Unit CapitalCrestwood Equity Partners LPClass D Units	Common Unit CapitalCrestwood Equity Partners LPClass C Units	Common Unit CapitalCrestwood Equity Partners LPPreferred Units, Class A	Non-Controlling Partners	Non-Controlling PartnersArrow Midstream Holdings, LLC	Non-Controlling PartnersCrestwood Equity Partners LP	Non-Controlling PartnersCrestwood Equity Partners LPArrow Midstream Holdings, LLC	Non-Controlling PartnersCrestwood Equity Partners LPCrestwood Marcellus Midstream LLC	Non-Controlling PartnersCrestwood Equity Partners LPClass D Units	Non-Controlling PartnersCrestwood Equity Partners LPClass C Units	Non-Controlling PartnersCrestwood Equity Partners LPPreferred Units, Class A
Balance at Dec. 31, 2012	$ 859.7		$ 1,550.7							$ 0		$ 0					$ 859.7		$ 31.7						$ 0		$ 0
Increase (Decrease) in Partners' Capital [Roll Forward]
Net proceeds from issuance of common units	714	$ 200	714	$ 200						0	$ 0	0	$ 0				714	$ 200	0	$ 0					0	$ 0	714	$ 200
Net proceeds from issuance of common units by subsidiaries					$ 0	$ 0									$ 0	$ 0						$ (126.3)	$ 0.6							$ 126.3	$ (0.6)
Issuance of preferred equity of subsidiary	96.1		96.1							0		0							0						96.1		96.1
Gain (loss) on issuance of subsidiary units												0							(12.6)								12.6
Issuance of Class A preferred units									$ 0
Exchange of Crestwood Midstream Partners LP units for CEQP units												0							182.3						(182.3)		(182.3)
Acquisition of non-controlling interest														$ 0							$ 238.9								$ (238.9)
Invested capital from Legacy Inergy, net of debt	3,827.8		3,379.4							0		0					3,827.8		697.1						0		2,682.3
Contribution from Crestwood Holdings LLC	15.5		10							0		0					15.5								0		10
Distributions to partners	(419.7)		(271.1)							0		0				$ 0	(419.7)		(56.6)				$ (0.1)		0		(214.5)				$ 0.1
Distribution for additional interest in Crestwood Marcellus Midstream LLC			(129)									0							(129)
Unit-based compensation charges	15.8		17.4							0		0					15.8		1.7						0		15.7
Taxes paid for unit-based compensation vesting	(5.5)		(8.3)							0		0					(5.5)		(2.8)						0		(5.5)
Change in fair value of Suburban units			(0.1)
Change in fair value of Suburban Propane Partners, L.P.			(0.1)									0							(0.1)
Other			0.1									0							0.1
Net income (loss)	(12.4)		(50.6)							0		0					(17.3)		6.7						4.9		(57.3)
Balance at Dec. 31, 2013	5,291.3		5,508.6							0		0					5,190.3		831.6						101		4,677
Increase (Decrease) in Partners' Capital [Roll Forward]
Issuance of preferred equity of subsidiary	53.9		53.9							0		0					0								53.9		53.9
Issuance of Class A preferred units	430.5		(430.5)						430.5	430.5		0					0								0		(430.5)
Change in invested capital from Legacy Inergy, net of debt	(15.3)		(15.3)							0		0					(15.3)		(10.5)						0		(4.8)
Distributions to partners	(470.5)		(399)							0		0					(470.5)		(102.5)						0		(296.5)
Unit-based compensation charges	18.1		21.3							0		0					18.1		3.9						0		17.4
Taxes paid for unit-based compensation vesting	(1.6)		(3.9)							0		0					(1.6)		(2.3)						0		(1.6)
Change in fair value of Suburban units			(0.5)
Change in fair value of Suburban Propane Partners, L.P.			(0.5)									0							(0.5)
Other	(0.7)		(0.7)							0		0					(0.7)		0.1						0		(0.8)
Net income (loss)	14.7		(10.4)							17.2		0					(19.3)		56.4						16.8		(66.8)
Balance at Dec. 31, 2014	$ 5,320.4		$ 5,584.5							447.7		0					4,701		776.2						171.7		4,808.3
Preferred Units, Outstanding at Dec. 31, 2014	17,917,870		0
Increase (Decrease) in Partners' Capital [Roll Forward]
Issuance of Class A preferred units	$ 58.8		$ (58.8)						58.8	58.8		0					0		0						0		(58.8)
Acquisition of non-controlling interest									$ 0															$ 3,294.8								$ (3,824.4)
Exchange of CMLP Class A preferred units for CEQP preferred units	0									(529.6)							529.6								0
Distributions to partners	(819.5)		(405.7)							0		0					(808.2)		(171.5)						(11.3)		(234.2)
Unit-based compensation charges	18.1		19.7							0		0					18.1		5.7						0		14
Taxes paid for unit-based compensation vesting	(2.1)		(3.7)							0		0					(2.1)		(1.6)						0		(2.1)
Change in fair value of Suburban units			(2.7)
Change in fair value of Suburban Propane Partners, L.P.			(2.7)									0							(2.7)								0
Other			(0.3)									0							(0.2)								(0.1)
Net income (loss)	(1,410.6)		(2,303.7)							23.1		6.2					(1,456.8)		(1,673.1)						23.1		(636.8)
Balance at Dec. 31, 2015	$ 3,165.1		$ 2,946.9							0		535.8					2,981.6		2,227.6						183.5		183.5
Common Unit, Outstanding at Dec. 31, 2015							68,200,000	400,000
Preferred Units, Outstanding at Dec. 31, 2015	0		60,718,245
Preferred Units, Outstanding at Sep. 30, 2015	21,580,244
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	$ (756.7)		$ (1,402.4)
Balance at Dec. 31, 2015	$ 3,165.1		$ 2,946.9							$ 0		535.8					2,981.6		2,227.6						183.5		183.5
Common Unit, Outstanding at Dec. 31, 2015							68,200,000	400,000
Preferred Units, Outstanding at Dec. 31, 2015	0		60,718,245
Preferred Stock Dividends, Shares			1,400,000
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners	$ (101)		$ (99.4)				$ 0	$ 0				0					(97.2)		(95.6)						(3.8)		(3.8)
Unit-based compensation charges	4.5		4.5					0				0					4.5		4.5						0		0
Partners' Capital Account, Units, Unit-based Compensation							900,000
Taxes paid for unit-based compensation vesting	(0.6)		(0.6)				$ 0	0				0					(0.6)		(0.6)						0		0
Change in fair value of Suburban units			0.8				0	0				0							0.8								0
Other	(0.1)		0.1				0	0									(0.1)		0.1						0		0
Net income (loss)	(95.3)		(93.7)				$ 0	$ 0				1.6					(101.2)		(101.2)						5.9		5.9
Balance at Mar. 31, 2016	$ 2,972.6		$ 2,758.6									$ 537.4					$ 2,787		$ 2,035.6						$ 185.6		$ 185.6
Common Unit, Outstanding at Mar. 31, 2016							69,100,000	400,000
Preferred Units, Outstanding at Mar. 31, 2016			62,122,562

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating activities
Net income (loss)	$ (95.3)	$ 29.1	$ (1,410.6)	$ 14.7	$ (12.4)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	64.9	68.8	278.5	255.4	139.4
Amortization of debt-related deferred costs and premiums	1.7	1.9	8.1	7.3	9.1
Unit-based compensation charges	4.5	5.2	18.1	18.1	15.8
(Gain) loss on long-lived assets, net	0	(0.8)	227.8	35.1	(5.3)
Goodwill impairment	109.7	0	1,149.1	48.8	4.1
Loss on contingent consideration			0	8.6	31.4
Loss on modification/extinguishment of debt			18.9	0	0
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	0.8	3.4	73.6	0.7	0.1
Deferred income taxes	0.2	0.1	(0.3)	0.7	0
Other	(0.1)	0	0.7	0	0.1
Changes in operating assets and liabilities, net of effects from acquisitions:
Accounts receivable			119.4	60.4	(39.9)
Inventory			2.1	26.9	(23.6)
Prepaid expenses and other current assets			3.7	(11.9)	5.9
Accounts payable, accrued expenses and other liabilities			(119.8)	25.8	101.3
Reimbursements of property, plant and equipment			73.3	21.5	0
Change in price risk management activities, net			29.2	(74.8)	27.7
Changes in operating assets and liabilities	50.7	3.2
Net cash provided by operating activities	135.7	105.7	471.8	437.3	253.7
Investing activities
Acquisitions, net of cash acquired (Note 3)			0	(19.5)	(561.5)
Purchases of property, plant and equipment	(55.6)	(47.4)	(182.7)	(421.7)	(339.3)
Investment in unconsolidated affiliates	(5.5)	(17.9)	(41.8)	(144.4)	(151.5)
Capital distributions from unconsolidated affiliates			9.3	0	0
Proceeds from sale of assets	0.8	0.5	2.7	2.7	11.2
Other	0	(0.2)
Net cash provided by (used in) investing activities	(60.3)	(65)	(212.5)	(582.9)	(1,041.1)
Financing activities
Proceeds from the issuance of long-term debt	313.5	1,114.6	3,490.1	2,089.9	2,072.8
Principal payments on long-term debt	(286)	(970.4)	(2,960.9)	(1,950)	(1,634.5)
Payments on capital leases	(0.5)	(0.7)	(2.2)	(3.2)	(4.3)
Payments for debt-related deferred costs	(0.1)	(11.1)	(17.3)	(0.1)	(32)
Financing fees paid for early debt redemption			13.6	0	0
Distributions to partners	(101)	(111.4)	(819.5)	(470.5)	(419.7)
Contributions from general partner	0	0	0	0	5.5
Net proceeds from issuance of common units			0	0	714
Net proceeds from issuance of Crestwood Midstream Partners LP common units					714
Net proceeds from issuance of Class A preferred units			0	53.9	96.1
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units			58.8	430.5
Taxes paid for unit-based compensation vesting	(0.6)	(1.7)	(2.1)	(1.6)	(5.5)
Other	0	(0.2)	(0.1)	(0.8)	0
Net cash provided by (used in) financing activities	(74.7)	19.1	(266.8)	148.1	792.4
Net change in cash	0.7	59.8	(7.5)	2.5	5
Cash at beginning of period	0.1	7.6	7.6	5.1	0.1
Cash at end of period	0.8	67.4	0.1	7.6	5.1
Cash paid during the period for interest			118.2	96.9	56.7
Cash paid during the period for income taxes			0.6	0.4	0
Supplemental schedule of non-cash investing and financing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	(9.7)	(9.1)	(14.1)	(40.6)	(30.5)
Acquisitions, net of cash acquired:
Current assets				0.5	240
Property, plant and equipment				13.5	2,076.8
Intangible assets				9.4	519.4
Goodwill				3.6	1,583.2
Other assets				0	22.3
Current liabilities				(2.7)	(243.9)
Debt				(3.5)	(745)
Invested capital of Crestwood Equity Partners LP, net of debt (Note 3)				0	(2,882.3)
Other liabilities				(1.3)	(9)
Total acquisitions, net of cash acquired				19.5	561.5
Crestwood Equity Partners LP
Operating activities
Net income (loss)	(93.7)	18.1	(2,303.7)	(10.4)	(50.6)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, amortization and accretion	62.3	74.2	300.1	285.3	167.9
Amortization of debt-related deferred costs and premiums	1.7	2.1	8.9	8.5	9.2
Market adjustment on interest rate swaps	0	(0.3)	(0.5)	(2.7)	(1.7)
Unit-based compensation charges	4.5	5.8	19.7	21.3	17.4
(Gain) loss on long-lived assets, net	0	(1)	821.2	1.9	(5.3)
Goodwill impairment	109.7	0	1,406.3	48.8	4.1
Loss on contingent consideration			0	8.6	31.4
Loss on modification/extinguishment of debt			20	0	0
Earnings from unconsolidated affiliates, net, adjusted for cash distributions received	(0.8)	(3.4)	73.6	0.7	0.1
Deferred income taxes	(0.1)	(0.9)	(3.6)	(5.2)	(2.8)
Other	0.1	0.4	0.7	0	(1)
Changes in operating assets and liabilities, net of effects from acquisitions:
Accounts receivable			119.7	60.4	(39.9)
Inventory			2	26.9	(23.6)
Prepaid expenses and other current assets			1.8	(11.4)	11.2
Accounts payable, accrued expenses and other liabilities			(128)	(96.4)	44.2
Reimbursements of property, plant and equipment			73.3	21.5	0
Change in price risk management activities, net			29.2	(74.8)	27.7
Changes in operating assets and liabilities	50.6	59.6
Net cash provided by operating activities	134.3	156.6	440.7	283	188.3
Investing activities
Acquisitions, net of cash acquired (Note 3)			0	(19.5)	(555.6)
Purchases of property, plant and equipment	(55.6)	(47.4)	(182.7)	(424)	(347)
Investment in unconsolidated affiliates	(5.5)	(18.1)	(42)	(108.6)	(151.5)
Capital distributions from unconsolidated affiliates			9.3	0	0
Proceeds from sale of Tres Palacios			0	66.4	0
Proceeds from sale of assets	0.8	0.5	2.7	2.7	11.2
Other	0	(0.2)
Net cash provided by (used in) investing activities	(60.3)	(65.2)	(212.7)	(483)	(1,042.9)
Financing activities
Proceeds from the issuance of long-term debt	313.5	1,252.7	4,261.8	2,823.9	2,466.9
Principal payments on long-term debt	(286.2)	(1,169.9)	(4,113)	(2,696)	(1,967.6)
Payments on capital leases	(0.5)	(0.7)	(2.2)	(3.2)	(4.3)
Payments for debt-related deferred costs	(0.1)	(11.1)	(17.3)	(1.9)	(33.1)
Financing fees paid for early debt redemption			(13.6)	0	0
Distributions to partners	(95.6)	(25.8)	(171.5)	(102.5)	(68.4)
Contributions from general partner	(3.8)	(74.3)	(234.2)	(296.5)	(204.5)
Distribution for additional interest in Crestwood Marcellus Midstream LLC			0	0	(129)
Net proceeds from issuance of Crestwood Midstream Partners LP common units			0	0	714
Net proceeds from issuance of Class A preferred units			0	53.9	96.1
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units			(58.8)	(430.5)
Taxes paid for unit-based compensation vesting	(0.6)	(3.1)	(3.8)	(3.9)	(10.5)
Other	(0.1)	(0.3)	(1.3)	(0.7)	0.1
Net cash provided by (used in) financing activities	(73.4)	(32.5)	(236.3)	203.6	859.7
Net change in cash	0.6	58.9	(8.3)	3.6	5.1
Cash at beginning of period	0.5	8.8	8.8	5.2	0.1
Cash at end of period	1.1	67.7	0.5	8.8	5.2
Cash paid during the period for interest			129	114.4	64.9
Cash paid during the period for income taxes			4.7	6.6	2.5
Supplemental schedule of non-cash investing and financing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$ (9.7)	$ (9.1)	(14.1)	(40.6)	(38)
Acquisitions, net of cash acquired:
Current assets				0.5	409.6
Property, plant and equipment				13.5	2,487.2
Intangible assets				9.4	660.9
Goodwill				3.6	2,195.4
Other assets				0	32.1
Current liabilities				(2.7)	(420.6)
Debt				(3.5)	(1,079.3)
Invested capital of Crestwood Equity Partners LP, net of debt (Note 3)				0	(3,579.4)
Other liabilities				(1.3)	(150.3)
Total acquisitions, net of cash acquired				19.5	555.6
Preferred Units, Class A
Financing activities
Net proceeds from issuance of Class A preferred units			58.8	430.5	0
Preferred Units, Class A | Crestwood Equity Partners LP
Financing activities
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units			$ 58.8	$ 430.5	$ 0

Organization and Business Descr

Organization and Business Description	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Text Block [Abstract]
Organization and Business Description	Note 1 – Organization and Business Description The accompanying notes to the consolidated financial statements apply to Crestwood Equity Partners LP and Crestwood Midstream Partners LP, unless otherwise indicated. References in this report to “we,” “us,” “our,” “ours,” “our company,” the “partnership,” the “Company,” “Crestwood Equity,” “CEQP,” and similar terms refer to either Crestwood Equity Partners LP itself or Crestwood Equity Partners and its consolidated subsidiaries, as the context requires. Unless otherwise indicated, references to “Crestwood Midstream” and “CMLP” refer to Crestwood Midstream Partners LP and its consolidated subsidiaries. The accompanying consolidated financial statements and related notes should be read in conjunction with our 2015 Annual Report on Form 10-K filed with the Securities and Exchange Commission (SEC) on February 29, 2016. The financial information as of March 31, 2016, and for the three months ended March 31, 2016 and 2015, is unaudited. The consolidated balance sheets as of December 31, 2015, were derived from the audited balance sheets filed in our 2015 Annual Report on Form 10-K. Organization Crestwood Equity is a publicly-traded (NYSE: CEQP) Delaware limited partnership that develops, acquires, owns or controls, and operates primarily fee-based assets and operations within the energy midstream sector. We provide broad-ranging infrastructure solutions across the value chain to service premier liquids-rich natural gas and crude oil shale plays across the United States. We own and operate a diversified portfolio of crude oil and natural gas gathering, processing, storage and transportation assets and connect fundamental energy supply with energy demand across North America. Crestwood Equity is a holding company and all of its consolidated operating assets are owned by or through its wholly-owned subsidiary, Crestwood Midstream, a Delaware limited partnership. Description of Business In conjunction with the Simplification Merger (as defined in Note 2), we modified our segments and our financial statements to reflect three operating and reporting segments: (i) gathering and processing operations; (ii) storage and transportation operations; and (iii) marketing, supply and logistics operations (formerly NGL and crude services operations). Consequently, the results of our Arrow operations are now reflected in our gathering and processing operations for all periods presented and our COLT and Powder River Basin Industrial Complex, LLC (PRBIC) operations are now reflected in our storage and transportation operations for all periods presented. These respective operations were previously included in our NGL and crude services operations. For a further description of our operating and reporting segments, see our 2015 Annual Report on Form 10-K.	Note 1— 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 Crestwood Midstream Partners LP Crestwood Merger (2013) Following the closing of the Crestwood Merger on October 7, 2013, Crestwood Holdings exchanged 7,100,000 common units of Crestwood Midstream for 14,300,000 of CEQP common units pursuant to an option granted to Crestwood Holdings when it acquired CEQP’s general partner. Simplification Merger (2015) Prior to the Simplification Merger, CEQP indirectly owned a non-economic general partnership interest in CMLP and 100% of its incentive distribution rights (IDRs), which entitled CEQP to receive 50% of all distributions paid by Crestwood Midstream in excess of its initial quarterly distribution of $0.37 per common unit. Crestwood Midstream’s common units were also listed on the New York Stock Exchange (NYSE) under the listing symbol “CMLP.” Upon becoming a wholly-owned subsidiary of CEQP as a result of the Simplification Merger, Crestwood Midstream’s IDRs were eliminated and its common units ceased to be listed on the NYSE. The diagram below reflects a simplified version of our ownership structure as of December 31, 2015: During the fourth quarter of 2015, Crestwood Holdings acquired 3,458,912 CEQP units from the public in a series of purchases. In January 2016, Crestwood Holdings acquired an additional 1,525,430 units from the public. Unless otherwise indicated, references in this report to “we,” “us,” “our,” “ours,” “our company,” the “partnership,” the “Company,” “Crestwood Equity,” 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 (i) the Crestwood Merger refers to the October 7, 2013 merger of the Company’s wholly-owned subsidiary with and into Legacy Crestwood, with Inergy Midstream continuing as the surviving legal entity; (ii) Legacy Inergy refers to either Inergy, L.P. itself or Inergy, L.P. and its consolidated subsidiaries prior to the Crestwood Merger, (iii) Inergy Midstream and NRGM refer to either Inergy Midstream, L.P. itself or Inergy Midstream, L.P. and its consolidated subsidiaries prior to the Crestwood Merger, (iv) Legacy Crestwood and Legacy CMLP refer to either Crestwood Midstream Partners LP itself or Crestwood Midstream Partners LP and its consolidated subsidiaries prior to the Crestwood Merger, and (v) Crestwood Midstream and CMLP refers to Crestwood Midstream Partners LP and its consolidated subsidiaries following the Crestwood Merger. See Note 3 for additional information on the Crestwood Merger. Description of Business Prior to the Simplification Merger, except for the assets comprising our proprietary NGL marketing business, all of our operating assets were owned by or through Crestwood Midstream. Crestwood Operations LLC (Crestwood Operations), a wholly-owned subsidiary of CEQP, owned and operated the assets comprising our proprietary NGL marketing business, consisting mainly of our West Coast NGL assets, our Seymour NGL storage facility, and our NGL transportation terminals and fleet. In connection with the closing of the Simplification Merger on September 30, 2015, CEQP contributed 100% of its interest in Crestwood Operations to Crestwood Midstream. As a result of this equity contribution, and as of December 31, 2015, substantially all of the Company’s consolidated assets are owned by or through Crestwood Midstream. In conjunction with the Simplification Merger described above, we modified our segments and our financial statements now reflect three operating and reporting segments: (i) gathering and processing operations; (ii) storage and transportation operations; and (iii) marketing, supply and logistics operations (formerly NGL and crude services operations). Consequently, the results of our Arrow operations are now reflected in our gathering and processing operations for all periods presented and our COLT operations and Powder River Basin Industrial Complex, LLC (PRBIC) investment are now reflected in our storage and transportation operations for all periods presented. These respective operations were previously included in our NGL and crude services operations. Below is a description of our operating and reporting segments. • Gathering and Processing • Storage and Transportation • Marketing, Supply and Logistics

Basis of Presentation and Summa

Basis of Presentation and Summary of Significant Accounting Policies	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Accounting Policies [Abstract]
Basis of Presentation and Summary of Significant Accounting Policies	Note 2 – Basis of Presentation and Summary of Significant Accounting Policies Basis of Presentation Our consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) and include the accounts of all consolidated subsidiaries after the elimination of all intercompany accounts and transactions. In management’s opinion, all necessary adjustments to fairly present our results of operations, financial position and cash flows for the periods presented have been made and all such adjustments are of a normal and recurring nature. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC. In May 2015, CEQP, Crestwood Midstream and certain of their affiliates entered into a definitive agreement under which Crestwood Midstream would merge with a wholly-owned subsidiary of CEQP, with Crestwood Midstream surviving as a wholly-owned subsidiary of CEQP (the Simplification Merger). In conjunction with the closing of the Simplification Merger on September 30, 2015, Crestwood Equity contributed 100% of its interest in Crestwood Operations LLC (Crestwood Operations) to Crestwood Midstream. As a result of this equity 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 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. Beginning in the third quarter of 2015, we changed our income statement to classify the revenues associated with the products to which we take title as product revenues in our consolidated statement of operations. As such, we reclassified our historical consolidated statement of operations for three months ended March 31, 2015 to reflect this change. We classify all other revenues as service revenues in our consolidated statement of operations. Significant Accounting Policies There were no material changes in our significant accounting policies from those described in our 2015 Annual Report on Form 10-K. Below is an update of our accounting policies related to Property, Plant and Equipment and Goodwill. Property, Plant and Equipment Property, plant and equipment is recorded at its original cost of construction or, upon acquisition, at the fair value of the assets acquired. The accounting predecessor of Crestwood Equity acquired the accounting predecessor of Crestwood Midstream in October 2010, and accordingly recorded its acquisition of Crestwood Midstream’s property, plant and equipment related to its gathering and processing assets in the Barnett Shale at fair value on that date. The resulting increase to Crestwood Midstream’s property, plant and equipment was not pushed down by Crestwood Equity to Crestwood Midstream’s balance sheet, as permitted by GAAP. We evaluate our long-lived assets for impairment whenever events or changes in circumstances indicate that the 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. During 2015, Crestwood Equity recorded a $354.4 million impairment of its property, plant and equipment related to its gathering and processing assets in the Barnett Shale. 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 of March 31, 2016 and December 31, 2015. 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 as of March 31, 2016 and December 31, 2015. 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. Commodity prices have continued to decline since 2014, and that decline has adversely impacted forecasted cash flows, discount rates and stock/unit prices for most companies in the midstream industry, including us. In particular, due to the significant, sustained decrease in the market price of our common units from January 1, 2016 to March 31, 2016, we evaluated the carrying value of our reporting units and determined it was more likely than not that the goodwill associated with several of our reporting units was impaired as of March 31, 2016. As a result of further analysis of the fair value of our reporting units, we recorded goodwill impairments on several of our reporting units during the three months ended March 31, 2016. The following table summarizes the goodwill of our various reporting units (in millions): Goodwill at December 31, 2015 Goodwill Impairments during the March 31, 2016 Goodwill at March 31, 2016 Gathering and Processing Marcellus $ 8.6 $ 8.6 $ — Arrow 45.9 — 45.9 Storage and Transportation Northeast Storage and Transportation 726.3 — 726.3 COLT 44.9 13.7 31.2 Marketing, Supply and Logistics Supply and Logistics 167.2 65.5 101.7 Storage and Terminals 50.5 14.1 36.4 US Salt 12.6 — 12.6 Trucking 29.5 7.8 21.7 Total $ 1,085.5 $ 109.7 $ 975.8 The goodwill impairments recorded during three months ended March 31, 2016 primarily resulted from increasing the discount rates utilized in determining the fair value of the reporting units considering the significant, sustained decrease in the market price of our common units and the continued decrease in commodity prices and its impact on the midstream industry and our customers. Our COLT, Supply and Logistics, Storage and Terminals and Trucking reporting units also experienced impairments during 2015 based on the impact that the prolonged low commodity price environment is expected to have on the demand for future services provided by these operations. Despite increases in the operating results of these reporting units from 2013 to 2015, in light of our modified expectations, we revised our cash flow forecasts for these operations at December 31, 2015 in light of our current view that these operations will not grow as fast or as significantly in the future as originally forecasted in 2013 when the assets were acquired. The remaining goodwill related to these reporting units represents the fair value of the goodwill as of March 31, 2016, which is a Level 3 fair value measurement. We utilized the income approach to determine the fair value of our reporting units given the limited availability of comparable market-based transactions as of March 31, 2016 and December 31, 2015, 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 March 31, 2016. We also used the market approach to validate the fair value of our Northeast Storage and Transportation reporting unit given the value to be received related to the anticipated Stagecoach joint venture transaction further described in Note 14. 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 six years. Effective January 1, 2016, we adopted the provisions of Accounting Standards Update (ASU) 2015-03, Interest - Imputation of Interest (Subtopic 835-30), Consolidations Effective 1, 2016, we adopted the provisions of ASU 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis New Accounting Pronouncements Issued But Not Yet Adopted As of March 31, 2016, the following accounting standards had not yet been adopted by us: In May 2014, the Financial Accounting Standards Board (FASB) issued ASU 2014-09, Revenue from Contracts with Customers, In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) In March 2016, the FASB issued ASU 2016-09, Compensation - Stock Compensation (Topic 718):Improvements to Employee Share-Based Payment Accounting	Note 2—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. Our consolidated financial statements for prior periods include reclassifications that were made 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. Crestwood Equity Crestwood Midstream In connection with the closing of the Simplification Merger on September 30, 2015, CEQP contributed 100% of its interest in Crestwood Operations to Crestwood Midstream. As a result of this equity contribution, 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. 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. 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. We use the cost method of accounting where we are unable to exert significant influence over the entity. In December 2014, Crestwood Equity sold its 100% interest in Tres Palacios Gas Storage Company LLC (Tres Palacios) to Tres Palacios Holdings LLC (Tres Holdings), a newly formed joint venture between Crestwood Midstream and an affiliate of Brookfield Infrastructure Group (Brookfield); consequently, Crestwood Equity deconsolidated Tres Palacios and began accounting for the investment in Tres Holdings under the equity method of accounting through its indirect ownership in Crestwood Midstream. See Note 6 for additional information related to the sale of Tres Palacios. 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 our storage and transportation operations and our marketing, supply and logistics operations are stated at the lower of cost or market and are computed predominantly using the average cost method. Our inventory consisted primarily of NGLs of approximately $35.4 million and $37.5 million at December 31, 2015 and 2014. 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 20 Facilities and equipment 20 – 25 Buildings, rights-of-way and easements 20 – 40 Office furniture and fixtures 5 – 10 Vehicles 5 We deplete salt deposits included in our property, plant and equipment utilizing the unit of production method. 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 2015 and 2014, we recorded the following impairments for our property, plant and equipment included in gain (loss) on long-lived assets in our consolidated statements of operations: • During 2015 and 2014, we incurred $8.5 million and $13.2 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 has declared bankruptcy and has ceased any substantial drilling in the Granite Wash in the near future given current and future anticipated market conditions related to normal gas and NGLs. The fair value of our property, plant and equipment related to our Granite Wash operations was $11.2 million as of December 31, 2015. • During 2015, Crestwood Equity incurred $354.4 million of impairments of its property, plant and equipment related to its Barnett gathering and processing operations, which resulted from the recent 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. The fair value of our property, plant and equipment related to our Barnett operations was $298.5 million as of December 31, 2015. • 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. The fair value of our property, plant and equipment related to our Fayetteville and Haynesville operations was $59.3 million and $3.8 million, respectively, as of December 31, 2015. • During 2015, we incurred $31.2 million of impairments on our property, plant and equipment related to our Watkins Glen development project in our marketing, supply and logistics segment, which resulted from continued delays and uncertainties in the permitting of our proposed NGL storage facility. The fair value of our property, plant and equipment related to our Watkins Glen development project was $6.7 million as of December 31, 2015. The remaining carrying value related to the property, plant and equipment associated with these assets represents the fair value of the property, plant and equipment as of December 31, 2015, which is a Level 3 fair value measurement. 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. 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, certain revenue contracts and deferred financing costs. 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. Deferred financing costs represent financing costs incurred in obtaining financing and are being amortized over the term of the related debt using a method which approximates the effective interest method and has a weighted average life of six years. 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 2015 and 2014, we recorded the following impairments of our intangible assets included in gain (loss) on long-lived assets in our consolidated statements of operations: • During 2014, we fully impaired $20 million of intangible assets 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 has declared bankruptcy and has ceased any 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 fully impaired $238.9 million of its intangible assets related to its Barnett gathering and processing operations, which resulted from the recent 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. The remaining carrying value related to these intangible assets represents the fair value of the intangible assets as of December 31, 2015, which is a Level 3 fair value measurement. 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. 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 22 Covenants not to compete 5 Trademarks 6 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. 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. Commodity prices have continued to decline since late 2014, and that decline 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 2015 and 2014. The following table summarizes the goodwill of our various reporting units (in millions): Goodwill at Final Goodwill Goodwill at Goodwill (1) Goodwill at Gathering and Processing Fayetteville $ 76.8 $ — $ 4.3 $ 72.5 $ 72.5 $ — Granite Wash 14.2 — 14.2 — — — Marcellus 8.6 — — 8.6 — 8.6 Arrow 45.5 0.4 — 45.9 — 45.9 Storage and Transportation Northeast Storage and Transportation 727.1 (0.8 ) — 726.3 — 726.3 COLT 670.5 (2.2 ) — 668.3 623.4 44.9 Marketing, Supply and Logistics West Coast 89.1 (3.2 ) — 85.9 85.9 — Supply and Logistics 269.5 (3.3 ) — 266.2 99.0 167.2 Storage and Terminals 104.7 (0.5 ) — 104.2 53.7 50.5 US Salt 16.1 (1.3 ) 2.2 12.6 — 12.6 Trucking 178.4 (0.5 ) — 177.9 148.4 29.5 Watkins Glen 94.6 (0.3 ) 28.1 66.2 66.2 — Total Crestwood Midstream $ 2,295.1 $ (11.7 ) $ 48.8 $ 2,234.6 $ 1,149.1 $ 1,085.5 Barnett (Gathering and Processing) 257.2 — — 257.2 257.2 — Total Crestwood Equity $ 2,552.3 $ (11.7 ) $ 48.8 $ 2,491.8 $ 1,406.3 $ 1,085.5 (1) Included in these amounts are approximately $515.4 million and $470.6 million of goodwill impairments recorded at Crestwood Equity and Crestwood Midstream, respectively, during the three months ended December 31, 2015, which primarily resulted from the finalization of the preliminary goodwill impairments recorded on these reporting units during the three months ended September 30, 2015. The goodwill impairments recorded during 2015 and 2014 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 discount rates ranging from 10% to 16% to determine the fair value of our reporting units as of December 31, 2015. The remaining goodwill related to these reporting units represents the fair value of the goodwill as of December 31, 2015, which is a Level 3 fair value measurement. Investment in Unconsolidated Affiliates We evaluate our equity method investments for impairment when events or circumstances indicate that the carrying value of the equity method investment may be impaired and that impairment is other than temporary. If an event occurs, we evaluate the recoverability of our carrying value based on the fair value of the investment. If an impairment is indicated, or if we decide to sell an investment in unconsolidated affiliate, we adjust the carrying values of the asset downward, if necessary, to their estimated fair values. We 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. 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. The remaining carrying value of $202.4 million and $15.1 million related to our Jackalope and PRBIC equity-method investments, respectively, represents the fair value of the equity-method investments as of December 31, 2015, which is a Level 3 fair value measurement. 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 right-of-way contracts we hold and our facilities whether owned or leased. 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, 2015 and 2014, our AROs were reflected in other long-term liabilities on our consolidated balance sheets. See Note 5 for a further discussion of our AROs. Revenue Recognition We gather, 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 marketing, supply and logistics operations, we take title to the underlying commodity. In the current year, we changed our income statement to classify the revenues associated with the products to which we take title as product revenues in our consolidated statement of operations. In addition, we also reclassified our historical consolidated statements of operations for the years ended December 31,2014 and 2013 to reflect this change. We classify 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, 2015 and 2014, we had deferred revenue of approximately $14.2 million and $12.2 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 least90% 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, 2015, 2014 or 2013. 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. New Accounting Pronouncements Issued But Not Yet Adopted As of December 31, 2015, the following accounting standards had not yet been adopted by us. In May 2014, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update 2014-09, Revenue from Contracts with Customers, In February 2015, the FASB issued Accounting Standards Update 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis, In April 2015, the FASB issued Accounting Standards Update 2015-03, Interest—Imputation of Interest (Subtopic 835-30) In February 2016, the FASB issued Accounting Standards Update 2016-02, Leases (Topic 842)

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2015
Business Combinations [Abstract]
Acquisitions	Note 3—Acquisitions 2014 Acquisitions Crude Transportation Acquisitions (Bakken) Red Rock LT Enterprises The acquisitions of Red Rock and LT Enterprises were not material to our marketing, supply and logistics segment’s results of operations for the year ended December 31, 2014. In addition, transaction costs related to these acquisitions were not material for the year ended December 31, 2014. 2013 Acquisitions Crestwood Merger As described in Note 2, the acquisition of Legacy Crestwood GP was accounted for as a reverse merger under the purchase method of accounting in accordance with the accounting standards for business combinations. This accounting treatment requires the accounting acquiree (Legacy Inergy) to have its assets and liabilities stated at fair value as well as any other purchase accounting adjustments as of June 19, 2013, the date of the acquisition. The fair value of Legacy Inergy was calculated based on the consolidated enterprise fair value of Legacy Inergy as of June 19, 2013. This consolidated enterprise fair value considered Legacy Inergy and Inergy Midstream’s (i) discounted future cash flows based on their operations; (ii) the stock prices of NRGY and NRGM; (iii) the value of their outstanding senior notes based on quoted market prices for same or similar issuances; (iv) the value of their outstanding floating rate debt; and (v) the value of IDRs of Crestwood Midstream. As discussed in Note 2, the Crestwood Merger was accounted for as a reverse merger amongst entities under common control. This accounting treatment requires the accounting acquiree (Inergy Midstream) to have its assets and liabilities stated at fair value as well as any other purchase accounting adjustments as of June 19, 2013, the date in which Legacy Crestwood and Inergy Midstream came under common control. The fair value of Legacy Inergy was calculated based on the consolidated enterprise value of Inergy Midstream as of June 19, 2013. This consolidated enterprise value considered Inergy Midstream’s (i) discounted future cash flows based on its operations; (ii) the stock price of Inergy Midstream; (iii) the value of its outstanding senior notes based on quoted market prices for same or similar issuances; and (iv) the value of its outstanding floating rate debt. In June 2014, we finalized the purchase price allocations for these reverse mergers. The following table summarizes the final valuation of the assets acquired and liabilities assumed at the merger date ( in millions CEQP CMLP Current assets $ 224.5 $ 49.1 Property, plant and equipment 2,088.1 1,677.8 Intangible assets 337.5 196.0 Other assets 12.7 2.9 Total identifiable assets acquired 2,662.8 1,925.8 Current liabilities 207.6 30.9 Long-term debt 1,079.3 745.0 Other long-term liabilities 146.6 5.3 Total liabilities assumed 1,433.5 781.2 Net identifiable assets acquired 1,229.3 1,144.6 Goodwill 2,134.8 1,532.7 Net assets acquired $ 3,364.1 $ 2,677.3 The amounts in the table above related to CMLP reflect historical purchase price allocation amounts and have not been recasted to reflect the contribution of Crestwood Operations to Crestwood Midstream as described in Note 1. Reductions of approximately $15.3 million from our preliminary estimates of the fair value of CEQP as of December 31, 2013 relate primarily to goodwill and were based on additional valuation information obtained on the components that comprised the enterprise fair value of Legacy Inergy as well as certain of our storage and transportation assets and obligations, primarily related to our Tres Palacios storage operations, which we previously consolidated. Of the$2,134.8 million of goodwill recorded at December 31, 2014 at CEQP as a result of the Crestwood Merger, $740.2 million was reflected in our marketing, supply and logistics segment and $1,394.6 million was reflected in our storage and transportation segment. Of the $1,532.7 million of goodwill recorded at December 31, 2014 at CMLP as a result of the Crestwood Merger, $138.1 million was reflected in our marketing, supply and logistics segment and $1,394.6 million was reflected in our storage and transportation segment. Goodwill recognized related primarily to synergies and new expansion opportunities expected to result from the combination of Legacy Crestwood and Legacy Inergy. During 2015 and 2014, we recorded impairments of goodwill for certain of our reporting units acquired in the Crestwood Merger. See Note 2 for a further discussion of our goodwill impairments. During the period from June 19, 2013 to December 31, 2013, CEQP and CMLP recognized $916.7 million and $902.6 million of operating revenues, respectively and $23.9 million and $32.8 million of operating income, respectively related to these reverse mergers. In addition, CEQP and CMLP recognized transaction costs related to the reverse mergers of approximately $3.4 million and $2.1 million, respectively for the year ended December 31, 2014 and $30.1 million and $24.7 million, respectively for the year ended December 31, 2013. These costs are reflected in general and administrative expenses in our consolidated statements of operations. Arrow Acquisition On November 8, 2013, Crestwood Midstream acquired Arrow Midstream Holdings, LLC (Arrow), a privately-held midstream company, for approximately $750 million, subject to customary capital expenditure and working capital adjustments of approximately $11.3 million, representations, warranties and indemnifications. The acquisition was consummated by merging a wholly-owned subsidiary of Crestwood Midstream with and into Arrow (the Arrow Acquisition), with Arrow continuing as the surviving entity and as a result, a wholly-owned subsidiary of Crestwood Midstream. The base merger consideration consisted of $550 million in cash and 8,826,125 common units of Crestwood Midstream issued to the sellers, subject to adjustment for standard working capital provisions. Arrow, through its wholly-owned subsidiaries, owns and operates substantial crude oil, natural gas and water gathering systems located on the Fort Berthold Indian Reservation in the core of the Bakken Shale in McKenzie and Dunn Counties, North Dakota. Arrow also owns salt water disposal wells and a 23-acre central delivery point with multiple pipeline take-away outlets and a fully-automated truck loading facility. In June 2014, we finalized the Arrow Acquisition purchase price allocation. The following table summarizes the final valuation of the assets acquired and liabilities assumed at the acquisition date ( in millions Current assets $ 192.7 Property, plant and equipment 400.5 Intangible assets 323.4 Other assets 19.5 Total identifiable assets acquired 936.1 Current liabilities 215.8 Assets retirement obligations 1.2 Other long-term liabilities 3.7 Total liabilities assumed 220.7 Net identifiable assets acquired 715.4 Goodwill 45.9 Net assets acquired $ 761.3 The $45.9 million of goodwill is reflected in our gathering and processing segment. Goodwill recognized related primarily to anticipated operating synergies between the assets acquired and our existing assets. During the year ended December 31, 2013, we recognized $218.8 million of operating revenues and $1.7 million of operating income related to this acquisition. Transaction costs related to the Arrow Acquisition were approximately $5.4 million and $1.2 million, for the years ended December 31, 2014 and 2013. These costs are included in general and administrative expenses in our consolidated statements of operations. Unaudited Pro Forma Information The following table presents unaudited pro forma consolidated revenues, net income and net income per limited partner unit as if the reverse mergers and the Arrow Acquisition had been included in our consolidated results for the entire year ended December 31, 2013 ( in millions, except per unit information CEQP CMLP Revenues $ 3,449.3 $ 3,423.8 Net income (loss) $ 3.9 $ (5.0 ) Net income per limited partner unit: Basic $ 0.40 Diluted $ 0.40 These amounts have been calculated after applying our accounting policies and adjusting the results of the acquisitions to reflect the depreciation and amortization based on the estimated fair value adjustments to property, plant and equipment and intangible assets.

Certain Balance Sheet Informati

Certain Balance Sheet Information	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Certain Balance Sheet Information	Note 3 – Certain Balance Sheet Information Accrued expenses and other liabilities consisted of the following at March 31, 2016 and December 31, 2015 ( in millions CEQP CMLP March 31, December 31, March 31, December 31, 2016 2015 2016 2015 Accrued expenses $ 30.7 $ 46.4 $ 29.0 $ 44.1 Accrued property taxes 5.4 4.8 5.4 4.8 Accrued product purchases payable 1.4 1.5 1.4 1.5 Tax payable 1.3 0.5 0.8 0.5 Interest payable 35.6 26.2 35.6 26.2 Accrued additions to property, plant and equipment 5.3 10.4 5.3 10.4 Capital leases 1.4 1.6 1.4 1.6 Deferred revenue 15.7 14.2 15.7 14.2 Total accrued expenses and other liabilities $ 96.8 $ 105.6 $ 94.6 $ 103.3	Note 4—Certain Balance Sheet Information Property, Plant and Equipment Property, plant and equipment of the following at December 31, 2015 and 2014 ( in millions CEQP CMLP December 31, December 31, 2015 2014 2015 2014 Gathering systems and pipelines $ 1,070.4 $ 1,410.9 $ 1,213.2 $ 1,279.5 Facilities and equipment 1,505.9 1,648.3 1,691.0 1,653.8 Buildings, land, rights-of-way, storage contracts and easements 833.4 841.5 837.1 840.0 Vehicles 46.3 45.2 44.6 43.5 Construction in process 114.5 156.5 114.5 156.5 Base gas 37.3 37.5 37.3 37.5 Salt deposits 120.5 120.5 120.5 120.5 Office furniture and fixtures 19.4 13.5 19.5 13.3 3,747.7 4,273.9 4,077.7 4,144.6 Less: accumulated depreciation and depletion 436.9 380.1 552.0 398.6 Total property, plant and equipment, net $ 3,310.8 $ 3,893.8 $ 3,525.7 $ 3,746.0 Depreciation. Capitalized Interest. Capital Leases. Intangible Assets Intangible assets consisted of the following at December 31, 2015 and 2014 ( in millions CEQP CMLP December 31, December 31, 2015 2014 2015 2014 Customer accounts $ 583.7 $ 583.7 $ 583.7 $ 583.7 Covenants not to compete 6.6 9.6 5.6 8.6 Gas gathering, compression and processing contracts 325.2 730.2 325.2 431.4 Acquired storage contracts 29.0 29.0 29.0 29.0 Trademarks 31.3 32.2 15.8 16.7 Deferred financing costs 63.3 57.2 63.3 54.3 1,039.1 1,441.9 1,022.6 1,123.7 Less: accumulated amortization 229.0 210.6 220.3 154.1 Total intangible assets, net $ 810.1 $ 1,231.3 $ 802.3 $ 969.6 The following table summarizes the total of accumulated amortization of intangible assets by the type of intangible asset at December 31, 2015 and 2014: CEQP CMLP December 31, December 31, 2015 2014 2015 2014 Customer accounts $ 130.1 $ 72.5 $ 130.1 $ 72.5 Covenants not to compete 2.5 3.2 1.7 2.6 Gas gathering, compression and processing contracts 44.3 98.0 44.3 47.9 Acquired storage contracts 18.5 12.7 18.5 12.7 Trademarks 11.2 6.7 3.3 2.0 Deferred financing costs 22.4 17.5 22.4 16.4 Total accumulated amortization $ 229.0 $ 210.6 $ 220.3 $ 154.1 Crestwood Equity’s amortization and interest expense related to its intangible assets for the years ended December 31, 2015, 2014 and 2013, was approximately $114.0 million, $109.8 million and $66.7 million. Crestwood Midstream’s amortization and interest expense related to its intangible assets for the years ended December 31, 2015, 2014 and 2013 was approximately $100.0 million, $92.1 million and $49.0 million. Estimated amortization of our intangible assets for the next five years is as follows ( in millions Year Ending December 31, CEQP CMLP 2016 $ 82.9 $ 79.6 2017 69.8 66.7 2018 57.4 55.9 2019 53.8 53.8 2020 52.6 52.6 Accrued Expenses and Other Liabilities Accrued expenses and other liabilities consisted of the following at December 31, 2015 and 2014 ( in millions CEQP CMLP December 31, December 31, 2015 2014 2015 2014 Accrued expenses $ 46.4 $ 52.5 $ 44.1 $ 50.0 Accrued property taxes 4.8 2.2 4.8 2.2 Accrued product purchases payable 1.5 0.7 1.5 0.7 Tax payable 0.5 1.6 0.5 1.2 Interest payable 26.2 23.5 26.2 21.9 Accrued additions to property, plant and equipment 10.4 20.0 10.4 20.0 Commitments and contingent liabilities ( Note 15 — 40.0 — 40.0 Capital leases 1.6 1.9 1.6 1.9 Deferred revenue 14.2 12.2 14.2 12.2 Total accrued expenses and other liabilities $ 105.6 $ 154.6 $ 103.3 $ 150.1

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Note 5—Asset Retirement Obligations We have legal obligations associated with right-of-way contracts we hold and at our facilities whether owned or leased. 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, 2015 and 2014 ( in millions December 31, 2015 2014 Net asset retirement obligation at January 1 $ 23.8 $ 15.1 Liabilities incurred 1.1 4.6 Acquisitions — 1.2 Accretion expense 1.5 1.1 Changes in estimate — 1.8 Net asset retirement obligation at December 31 $ 26.4 $ 23.8 We did not have any material assets that were legally restricted for use in settling asset retirement obligations as of December 31, 2015 and 2014.

Investments in Unconsolidated A

Investments in Unconsolidated Affiliates	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Equity Method Investments and Joint Ventures [Abstract]
Investments in Unconsolidated Affiliates	Note 4 - Investments in Unconsolidated Affiliates Net Investments and Earnings Our net investments in and earnings from our unconsolidated affiliates are as follows ( in millions, unless otherwise stated Ownership Investment Earnings from Unconsolidated March 31, March 31, December 31, Three Months Ended March 31, 2016 2016 2015 2016 2015 Jackalope Gas Gathering Services, L.L.C. (1) 50.00 % (4) $ 202.4 $ 202.4 $ 5.1 $ 2.5 Tres Palacios Holdings LLC (2) 50.01 % 43.1 36.8 0.8 0.9 Powder River Basin Industrial Complex, LLC (3) 50.01 % 15.1 15.1 0.6 — Total $ 260.6 $ 254.3 $ 6.5 $ 3.4 (1) As of March 31, 2016, our equity in the underlying net assets of Jackalope Gas Gathering Services, L.L.C. (Jackalope) exceeded our investment balance by approximately $0.9 million. We amortize this amount over 20 years, which represents the life of Jackalope’s gathering agreement with Chesapeake Energy Corporation (Chesapeake), and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of less than $0.1 million and $0.8 million for the three months ended March 31, 2016 and 2015. Our Jackalope investment is included in our gathering and processing segment. (2) As of March 31, 2016, our equity in the underlying net assets of Tres Palacios Holdings LLC (Tres Holdings) exceeded our investment balance by approximately $28.8 million. We amortize this amount over the life of the Tres Palacios Gas Storage LLC (Tres Palacios) sublease agreement, and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of $0.3 millionduring each of the three months ended March 31, 2016 and 2015. Our Tres Holdings investment is included in our storage and transportation segment. (3) As of March 31, 2016, our equity in the underlying net assets of PRBIC exceeded our investment balance by approximately $23.0 million. We amortize this amount over the life of PRBIC’s property, plant and equipment and its agreement with Chesapeake, and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of approximately $0.4 million for the three months ended March 31, 2016. Our PRBIC investment is included in our storage and transportation segment. (4) Excludes non-controlling interests related to our investment in Jackalope. See Note 9 for a further discussion of our non-controlling interest related to our investment in Jackalope. Distributions and Contributions Jackalope. Tres Holdings. PRBIC.	Note 6—Investments in Unconsolidated Affiliates Net Investments and Earnings (Loss) Ownership Investment Earnings (Loss) from December 31, 2015 December 31, Year Ended December 31, 2015 2014 2015 2014 2013 Jackalope Gas Gathering Services, L.L.C. (1) 50.00 % (4) $ 202.4 $ 232.9 $ (43.4 ) (5) $ 0.5 $ 0.1 Tres Palacios Holdings LLC (2) 50.01 % 36.8 36.0 2.5 0.2 — Powder River Basin Industrial Complex, LLC (3) 50.01 % 15.1 26.2 (19.9 ) (5) (1.4 ) (0.2 ) Total $ 254.3 $ 295.1 $ (60.8 ) $ (0.7 ) $ (0.1 ) (1) As of December 31, 2015, our equity in the underlying net assets of Jackalope exceeded our investment balance by approximately $0.9 million. We amortize this amount over 20 years, which represents the life of Jackalope’s gathering agreement with Chesapeake Energy Corporation (Chesapeake), and we reflect the amortization as a reduction of our earnings from unconsolidated affiliates. We recorded amortization of approximately $3.0 million, $3.1 million and $1.4 million for the years ended December 31, 2015, 2014 and 2013. (2) As of December 31, 2015, our equity in the underlying net assets of Tres Holdings exceeded our investment balance by approximately $29.1 million. We amortize and generally assess the recoverability of this amount over the life of the Tres Palacios Gas Storage LLC (Tres Palacios) sublease agreement, and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of approximately $1.3 million and $0.1 million for the years ended December 31, 2015 and 2014. (3) As of December 31, 2015, our equity in the underlying net assets of PRBIC exceeded our investment balance by approximately $23.4 million. We amortize this amount over the life of PRBIC’s property, plant and equipment and its agreement with Chesapeake. During the three months ended June 30, 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. (4) Excludes non-controlling interests related to our investment in Jackalope. See Note 12 for a further discussion of our non-controlling interest related to our investment in Jackalope. (5) During the year ended December 31, 2015, we recorded impairments of our Jackalope and PRBIC equity investments of approximately $51.4 million and $23.4 million. For a further discussion of these impairments, see Note 2. Description of Investments Jackalope. We entered into a construction agreement with Jackalope, pursuant to which we assumed the responsibility to construct a truck terminal and storage facility. Under this agreement, Jackalope reimburses us for all costs incurred on its behalf, therefore, no revenues are recognized under this agreement. Tres Palacios Holdings LLC In December 2014, CEQP sold its 100% interest in Tres Palacios to Tres Holdings, a newly formed joint venture between Crestwood Midstream’s consolidated subsidiary and an affiliate of Brookfield, for total cash consideration of approximately $132.8 million, of which $66.4 million was paid by Crestwood Midstream. As a result of this transaction, effective December 1, 2014, CEQP deconsolidated the operations of Tres Palacios. Crestwood Midstream owns 50.01% of Tres Holdings and is the operator of Tres Palacios and its assets. Brookfield owns the remaining 49.99% interest in Tres Holdings. We account for our investment in Tres Holdings under the equity method of accounting, and the investment is included in our storage and transportation segment. The sale of CEQP’s 100% interest in Tres Palacios was accounted for under the accounting standards related to in substance real estate transactions. The accounting for the sale of real estate results in the recognition of a gain to the extent the sale is to an independent buyer. Since CEQP retained 50.01% of its interest in Tres Palacios through its ownership in Crestwood Midstream, CEQP recognized only the portion of the gain related to sale to Brookfield of approximately $30.6 million and, as a result, no gain was recognized on the portion of the sale between Crestwood Midstream and CEQP. The sale of CEQP’s interest in Tres Palacios to Crestwood Midstream was considered a transaction between entities under common control and, as a result, Crestwood Midstream reflected its investment at approximately $35.8 million, which represented 50.01% of CEQP’s historical basis in Tres Palacios. Tres Palacios owns a FERC-certificated 38.4 Bcf multi-cycle, salt dome natural gas storage facility. Its 63-mile, dual 24-inch diameter header system (including a 52-mile north pipeline lateral and an approximate 11-mile south pipeline lateral) interconnects with 10 pipeline systems and can receive residue gas from the tailgate of Kinder Morgan Inc.’s Houston central processing plant. 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. During the years ended December 31, 2015 and 2014, Tres Palacios reimbursed us approximately $2.8 million and $0.2 million under this agreement. These reimbursements are reflected as a reduction of operations and maintenance expense in our consolidated statements of operations. In addition to our operating agreement, CEQP also entered into an indemnification agreement with Tres Palacios to indemnify Tres Palacios for property tax liabilities associated with periods prior to the sale. Pursuant to the indemnification agreement, any property tax refunds received by Tres Palacios will be payable to CEQP. 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. Our PRBIC investment is included in our storage and transportation segment. In September 2013, Crude Logistics and Enserco Midstream, LLC formed PRBIC to construct, own and operate an integrated crude oil loading, storage and pipeline terminal located in Douglas County, Wyoming. The terminal was placed in manifest service in August 2013 and unit train in service in May 2014. Crude Logistics paid approximately $22.5 million to acquire its interest in PRBIC. Distributions and Contributions Jackalope. Tres Holdings. PRBIC.

Risk Management

Risk Management	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Risk Management	Note 5 – 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 6. Commodity Derivative Instruments and Price Risk Management Risk Management Activities We sell NGLs 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 three months ended March 31, 2016 and 2015, the impact to the statement of operations related to our commodity-based derivatives reflected in costs of product/services sold was a gain of $1.2 million and a loss of $2.9 million. 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 at March 31, 2016 and December 31, 2015 ( in millions March 31, 2016 December 31, 2015 Fixed Price Payor Fixed Price Receiver Fixed Price Payor Fixed Price Receiver Propane, crude and heating oil ( barrels 10.6 11.9 9.1 10.9 Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly, notional amounts do not reflect our monetary exposure to market or credit risks. All contracts subject to price risk had a maturity of 36 months or less; however, 81% of the contracted volumes will be delivered or settled within 12 months. Credit Risk Inherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. The counterparties associated with our assets from price risk management activities as of March 31, 2016 and December 31, 2015 were energy marketers and propane retailers, resellers and dealers. Certain of our derivative instruments have credit limits that require us to post collateral. The amount of collateral required to be posted is a function of the net liability position of the derivative as well as our established credit limit with the respective counterparty. If our credit rating were to change, the counterparties could require us to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent of change in our credit rating as well as the requirements of the individual counterparty. The aggregate fair value of all commodity derivative instruments with credit-risk-related contingent features that were in a liability position at March 31, 2016 and December 31, 2015 was $3.8 million and $3.3 million. At March 31, 2016, we posted $0.3 million of collateral in the normal course of business. We did not post collateral at December 31, 2015 for our commodity derivative instruments with credit-risk-related contingent features. In addition, at March 31, 2016 and December 31, 2015, we had a New York Mercantile Exchange (NYMEX) related net derivative liability position of $3.1 million and $20.8 million, for which we posted $9.5 million and $26.7 million of cash collateral in the normal course of business. At March 31, 2016 and December 31, 2015, we also received collateral of $7.1 million and $16.8 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.	Note 7—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. We also periodically utilize derivative instruments to manage our exposure to fluctuations in interest rates, which is discussed in Note 9. 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 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 will 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, 2015, 2014 and 2013, the impact to the statement of operations related to our commodity-based derivatives reflected in costs of product/services sold was a gain of $18.9 million, a gain of $51.2 million and a loss of $11.2 million. 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 at December 31, 2015 and 2014( in millions December 31, 2015 December 31, 2014 Fixed Price Payor Fixed Price Receiver Fixed Price Payor Fixed Price Receiver Propane, crude and heating oil ( barrels 9.1 10.9 6.8 8.4 Natural gas ( MMBTU’s — — 0.2 0.1 Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly, notional amounts do not reflect our monetary exposure to market or credit risks. All contracts subject to price risk had a maturity of 36 months or less; however, 84% of the contracts expire within 12 months. Credit Risk Inherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. The counterparties associated with our assets from price risk management activities as of December 31, 2015 and 2014 were energy marketers and propane retailers, resellers and dealers. Certain of our derivative instruments have credit limits that require us to post collateral. The amount of collateral required to be posted is a function of the net liability position of the derivative as well as our established credit limit with the respective counterparty. If our credit rating were to change, the counterparties could require us to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent of change in our credit rating as well as the requirements of the individual counterparty. The aggregate fair value of all commodity derivative instruments with credit-risk-related contingent features that were in a liability position at December 31, 2015 and 2014, was $3.3 million and $5.2 million. At December 31, 2014 we posted $1.8 million of collateral in the normal course of business. We did not post collateral at December 31, 2015 for our commodity derivative instruments with credit-risk-related contingent features. In addition, at December 31, 2015 and 2014, we had a New York Mercantile Exchange (NYMEX) related net derivative liability position of $20.8 million and $36.9 million, for which we posted $26.7 million and $41.9 million of cash collateral in the normal course of business. At December 31, 2015 and 2014, we also received collateral of $16.8 million and $33.6 million in the normal course of business. All collateral amounts have been netted against the asset or liability with the respective counterparty and is reflected in our consolidated balance sheets as assets and liability from price risk management activities.

Fair Value Measurements

Fair Value Measurements	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 6 – Fair Value Measurements The accounting standards for fair value measurement establish 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 and Cash Equivalents, Accounts Receivable and Accounts Payable As of March 31, 2016 and December 31, 2015, the carrying amounts of cash, accounts receivable and accounts payable represent fair value based on the short-term nature of these instruments. Credit Facility The fair value of the amount outstanding under our CMLP credit facility approximates its carrying amount as of March 31, 2016 and December 31, 2015, 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 and fair value of our CMLP senior notes ( in millions March 31, 2016 December 31, 2015 Carrying Amount Fair Value Carrying Fair Value Crestwood Midstream 2020 Senior Notes $ 503.2 $ 399.8 $ 503.3 $ 382.3 Crestwood Midstream 2022 Senior Notes $ 600.0 $ 446.0 $ 600.0 $ 437.4 Crestwood Midstream 2023 Senior Notes $ 700.0 $ 519.8 $ 700.0 $ 491.8 Financial Assets and Liabilities As of March 31, 2016 and December 31, 2015, 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. Certain of our derivative instruments are traded on the NYMEX. These instruments 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 March 31, 2016 and December 31, 2015 ( in millions March 31, 2016 Fair Value of Derivatives Level 1 Level 2 Level 3 Gross Fair Contract (1) Collateral/Margin Received or Paid Recorded in Assets Assets from price risk management $ 0.4 $ 32.2 $ — $ 32.6 $ (19.7 ) $ 1.5 $ 14.4 Suburban Propane Partners, L.P. units (2) 4.2 — — 4.2 — — 4.2 Total assets at fair value $ 4.6 $ 32.2 $ — $ 36.8 $ (19.7 ) $ 1.5 $ 18.6 Liabilities Liabilities from price risk management $ 0.2 $ 26.6 $ — $ 26.8 $ (19.7 ) $ 0.2 $ 7.3 Total liabilities at fair value $ 0.2 $ 26.6 $ — $ 26.8 $ (19.7 ) $ 0.2 $ 7.3 December 31, 2015 Fair Value of Derivatives Level 1 Level 2 Level 3 Gross Fair Contract (1) Collateral/Margin Received Recorded in Assets Assets from price risk management $ 0.5 $ 57.8 $ — $ 58.3 $ (13.7 ) $ (12.0 ) $ 32.6 Suburban Propane Partners, L.P. units (2) 3.4 — — 3.4 — — 3.4 Total assets at fair value $ 3.9 $ 57.8 $ — $ 61.7 $ (13.7 ) $ (12.0 ) $ 36.0 Liabilities Liabilities from price risk management $ 0.2 $ 41.3 $ — $ 41.5 $ (13.7 ) $ (20.4 ) $ 7.4 Total liabilities at fair value $ 0.2 $ 41.3 $ — $ 41.5 $ (13.7 ) $ (20.4 ) $ 7.4 (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.	Note 8—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 physical exchanges and interest rate swaps. • 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, 2015 and 2014, the carrying amounts of cash, accounts receivable and accounts payable represent fair value based on the short-term nature of these instruments. Credit Facilities The fair value of the amounts outstanding under our credit facilities approximates their carrying amounts as of December 31, 2015 and 2014, due primarily to the variable nature of the interest rates of the instruments, 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 and fair value of the senior notes ( in millions December 31, 2015 December 31, 2014 Carrying Fair Value Carrying Fair CEQP Senior Notes $ — $ — $ 11.4 $ 11.6 Crestwood Midstream 2019 Senior Notes $ — $ — $ 351.0 $ 360.5 Crestwood Midstream 2020 Senior Notes $ 503.3 $ 382.3 $ 504.0 $ 481.6 Crestwood Midstream 2022 Senior Notes $ 600.0 $ 437.4 $ 600.0 $ 568.5 Crestwood Midstream 2023 Senior Notes $ 700.0 $ 491.8 $ — $ — Financial Assets and Liabilities As of December 31, 2015, and 2014, we held certain financial assets and liabilities that are required to be measured at fair value on a recurring basis, which include our derivative instruments related to heating oil, crude oil, NGLs and interest rates. Our derivative instruments consist of forwards, swaps, futures, physical exchanges and options. Certain of our derivative instruments are traded on the NYMEX. These instruments 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, 2015 and 2014 ( in millions December 31, 2015 Fair Value of Derivatives Level 1 Level 2 Level 3 Gross Contract (1) Collateral/Margin Recorded in Assets Assets from price risk management $ 0.5 $ 57.8 $ — $ 58.3 $ (13.7 ) $ (12.0 ) $ 32.6 Suburban Propane Partners, L.P. units (2) 3.4 — — 3.4 — — 3.4 Total assets at fair value $ 3.9 $ 57.8 $ — $ 61.7 $ (13.7 ) $ (12.0 ) $ 36.0 Liabilities Liabilities from price risk management $ 0.2 $ 41.3 $ — $ 41.5 $ (13.7 ) $ (20.4 ) $ 7.4 Total liabilities at fair value $ 0.2 $ 41.3 $ — $ 41.5 $ (13.7 ) $ (20.4 ) $ 7.4 December 31, 2014 Fair Value of Derivatives Level 1 Level 2 Level 3 Gross Contract (1) Collateral/Margin Recorded in Assets Assets from price risk management $ 0.5 $ 146.7 $ — $ 147.2 $ (28.8 ) $ (38.6 ) $ 79.8 Suburban Propane Partners, L.P. units (2) 6.1 — — 6.1 — — 6.1 Total assets at fair value $ 6.6 $ 146.7 $ — $ 153.3 $ (28.8 ) $ (38.6 ) $ 85.9 Liabilities Liabilities from price risk management $ 1.6 $ 99.2 $ — $ 100.8 $ (28.8 ) $ (46.6 ) $ 25.4 Interest rate swaps (3) — 1.6 — 1.6 — — 1.6 Total liabilities at fair value $ 1.6 $ 100.8 $ — $ 102.4 $ (28.8 ) $ (46.6 ) $ 27.0 (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 the Crestwood Equity Partners LP consolidated balance sheet. (3) Our interest rate swaps are only reflected in the consolidated results of Crestwood Equity. See Note 9 for a further discussion of our interest rate swaps.

Long-Term Debt

Long-Term Debt	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Debt Disclosure [Abstract]
Long-Term Debt	Note 7 – Long-Term Debt Long-term debt consisted of the following at March 31, 2016 and December 31, 2015 ( in millions March 31, 2016 December 31, 2015 Credit Facility $ 762.8 $ 735.0 2020 Senior Notes 500.0 500.0 Fair value adjustment of 2020 Senior Notes 3.2 3.3 2022 Senior Notes 600.0 600.0 2023 Senior Notes 700.0 700.0 Other 4.9 5.3 Less: deferred financing costs, net 39.2 40.9 Total Crestwood Midstream debt 2,531.7 2,502.7 Other — 0.2 Total Crestwood Equity debt 2,531.7 2,502.9 Less: current portion 0.9 1.1 Total long-term debt, less current portion $ 2,530.8 $ 2,501.8 Crestwood Midstream Credit Facility At March 31, 2016, Crestwood Midstream had $268.2 million of available capacity under its credit facility considering the most restrictive debt covenants in its credit agreement. At March 31, 2016 and December 31, 2015, Crestwood Midstream’s outstanding standby letters of credit were $60.7 million and $62.2 million. Borrowings under the CMLP credit facility accrue interest at prime or Eurodollar based rates plus applicable spreads, which resulted in interest rates between 2.94% and 5.00% at March 31, 2016 and 2.70% and 5.00% at December 31, 2015. The weighted-average interest rate as of March 31, 2016 and December 31, 2015 was 2.96% and 2.70%. 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 March 31, 2016, the net debt to consolidated EBITDA was approximately 4.98 to 1.0, the consolidated EBITDA to consolidated interest expense was approximately 3.77 to 1.0, and the senior secured leverage ratio was 1.48 to 1.0. Crestwood Midstream Senior Notes On March 7, 2016, Crestwood Midstream filed a registration statement with the SEC under which it plans to offer to exchange $700.0 million of its 6.25% unsecured Senior Notes due 2023 (2023 Senior Notes) for any and all outstanding notes. The terms of the exchange notes are substantially identical to the terms of the 2023 Senior Notes, except that the exchange notes will be freely tradable. Crestwood Midstream issued the 2023 Senior Notes in March 2015. The net proceeds from this offering of approximately $688.3 million were used to pay down borrowings under the Crestwood Midstream $1.0 billion credit facility and for Crestwood Midstream’s general partnership purposes. At March 31, 2016, Crestwood Midstream was in compliance with all of its debt covenants applicable to the CMLP credit facility and its senior notes.	Note 9—Long-Term Debt Long-term debt consisted of the following at December 31, 2015 and 2014, ( in millions December 31, December 31, CMLP Credit Facility $ 735.0 $ 555.0 Crestwood Midstream 2019 Senior Notes — 350.0 Premium on Crestwood Midstream 2019 Senior Notes — 1.0 Crestwood Midstream 2020 Senior Notes 500.0 500.0 Fair value adjustment of Crestwood Midstream 2020 Senior Notes 3.3 4.0 Crestwood Midstream 2022 Senior Notes 600.0 600.0 Crestwood Midstream 2023 Senior Notes 700.0 — Other 5.3 5.3 Total Crestwood Midstream debt 2,543.6 2,015.3 CEQP Credit Facility — 369.0 CEQP Senior Notes — 11.4 Other 0.2 0.8 Total Crestwood Equity debt 2,543.8 2,396.5 Less: current portion 1.1 3.7 Total long-term debt, less current portion $ 2,542.7 $ 2,392.8 Crestwood Equity Long-Term Debt CEQP Credit Facility In conjunction with the closing of the Simplification Merger, we terminated the CEQP Credit Facility, repaid all borrowings and retired all standby letters of credit outstanding under the facility. We recognized a loss on extinguishment of debt of approximately $0.9 million in conjunction with the termination of the CEQP Credit Facility. At December 31, 2014, our outstanding standby letters of credit were $56.7 million. The interest rates on the CEQP Credit Facility were based on the prime rate and LIBOR plus the applicable spreads, resulting in interest rates which were between 2.91% and 5.00% at December 31, 2014. The weighted-average interest rate as of December 31, 2014 was 3.02%. CEQP Interest Rate Swaps CEQP Senior Notes During the year ended December 31, 2015, we repaid the balance outstanding under our senior notes, the majority of which were scheduled to mature on October 1, 2018. We recognized a loss on extinguishment of debt of approximately $0.2 million for the year ended December 31, 2015 in conjunction with the redemption of our senior notes. Crestwood Midstream Long-Term Debt CMLP Credit Facility Prior to amending and restating its credit agreement, Crestwood Midstream had a five-year $1.0 billion senior secured revolving credit facility, which would have expired October 2018. We recognized a loss on extinguishment of debt of approximately $1.8 million 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, 2015, the balance outstanding under the CMLP Credit Facility was $735.0 million and its outstanding standby letters of credit were $62.2 million. At December 31, 2015, Crestwood Midstream had $399.0 million of available capacity under the CMLP Credit Facility considering the most restrictive debt covenants in its credit agreement. Borrowings under the CMLP Credit Facility accrue interest at prime or Eurodollar based rates plus applicable spreads, which resulted in interest rates between 2.70% and 5.00% at December 31, 2015. The weighted-average interest rate as of December 31, 2015 was 2.70%. At December 31, 2014, the balance outstanding under the Crestwood Midstream $1.0 billion credit facility was $555.0 million and its outstanding letters of credit were $15.1 million. Borrowings under the $1.0 billion credit facility accrued interest at prime or LIBOR-based rates plus applicable spreads, which resulted in interest rates between 2.66% and 4.75% at December 31, 2014. The weighted-average interest rate as of December 31, 2014 was 2.86%. 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. 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, 2015, the net debt to consolidated EBITDA was approximately 4.75 to 1.0, the consolidated EBITDA to consolidated interest expense was approximately 3.99 to 1.0, and the senior secured leverage ratio was 1.37 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. Crestwood Midstream Senior Notes 2019 Senior Notes 2020 Senior Notes 2022 Senior Notes On July 17, 2014, Crestwood Midstream filed a registration statement with the SEC under which it offered to exchange the 2022 Senior Notes for any and all outstanding 2022 Senior Notes. Crestwood Midstream completed the exchange offer on August 29, 2014. The terms of the exchange notes are substantially identical to the terms of the 2022 Senior Notes, except that the exchange notes are freely tradable. 2023 Senior Notes 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 Crestwood Midstream Revolver. 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, 2015, 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 $2,981.6 million as of December 31, 2015. Notes Payable and Other Obligations CEQP’s non-interest bearing obligations due under noncompetition agreements and other note payable agreements consisted of agreements between Legacy Inergy and the sellers of certain companies acquired from 2003 through 2014 with payments due through 2027 and imputed interest ranging from 5.02% to 8.00%. At December 31, 2015 and 2014, CEQP’s non-interest bearing obligations consisted of $6.8 million and $7.4 million in total payments due under agreements, less unamortized discount based on imputed interest of $1.3 million in both periods. CMLP’s non-interest bearing obligations due under noncompetition agreements consisted of agreements between Crestwood Midstream and sellers of certain companies acquired in 2014 with payments due through 2027 and imputed interest ranging from 5.02% to 8.00%. Non-interest bearing obligations consisted of $6.6 million and $6.5 million in total payments due under agreements, less unamortized discount based on imputed interest of $1.3 million and $1.2 million at December 31, 2015 and 2014, respectively. Maturities The aggregate maturities of principal amounts on our outstanding long-term debt and other notes payable as of December 31, 2015 for the next five years and in total thereafter are as follows ( in millions CEQP CMLP 2016 $ 1.1 $ 0.9 2017 1.0 1.0 2018 1.0 1.0 2019 1.1 1.1 2020 1,238.6 1,238.6 Thereafter 1,301.0 1,301.0 Total debt $ 2,543.8 $ 2,543.6 Residual Value Guarantee In August 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 directly to, or to 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 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 Un

Earnings Per Limited Partner Unit	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Limited Partner Unit	Note 8 - Earnings Per Limited Partner Unit Our net income (loss) attributable to Crestwood Equity Partners is allocated to the subordinated and limited partner unitholders based on their ownership percentage after giving effect to net income attributable to the Class A preferred units. We calculate basic net income per limited partner unit using the two-class method. Diluted net income per limited partner unit is computed using the treasury stock method, which considers the impact to net income attributable to Crestwood Equity Partners and limited partner units from the potential issuance of limited partner units. We exclude potentially dilutive securities from the determination of diluted earnings per unit (as well as their related income statement impacts) when their impact on net income attributable to Crestwood Equity Partners per limited partner unit is anti-dilutive. During the three months ended March 31, 2016, we excluded a weighted-average of 6,212,256 common units (representing preferred units), a weighted-average of 438,789 common units (representing subordinated units), and a weighted-average of 19,262,780 common units (representing Crestwood Niobrara’s preferred units). See Note 9 for additional information regarding the potential conversion of our preferred units and Crestwood Niobrara’s preferred units to common units. There were no units excluded from our dilutive earnings per unit as we did not have any anti-dilutive units for the three months ended March 31, 2015.	Note 10—Earnings Per Limited Partner Unit CEQP Reverse Split 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 Class A 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 year ended December 31, 2015, we excluded a weighted-average of 1,547,060 common units (representing preferred units), a weighted-average of 438,789 common units (representing subordinated units), and a weighted-average of 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.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Note 11—Income Taxes The provision (benefit) for income taxes for the years ended December 31, 2015, 2014, and 2013 consisted of the following (in millions) CEQP CMLP Year Ended December 31, Year Ended December 31, 2015 2014 2013 2015 2014 2013 Current: Federal $ 1.6 $ 5.0 $ 2.5 $ — $ — $ — State 0.6 1.3 1.3 0.3 0.2 0.7 Total current 2.2 6.3 3.8 0.3 0.2 0.7 Deferred: Federal (2.9 ) (5.3 ) (2.5 ) — — — State (0.7 ) 0.1 (0.3 ) (0.3 ) 0.7 — Total deferred (3.6 ) (5.2 ) (2.8 ) (0.3 ) 0.7 — Provision (benefit) for income taxes $ (1.4 ) $ 1.1 $ 1.0 $ — $ 0.9 $ 0.7 The effective rate differs from the statutory rate for the years ended December 31, 2015 and 2014, 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. Components of our deferred income taxes at December 31, 2015 and 2014 are as follows (in millions). CEQP CMLP December 31, December 31, 2015 2014 2015 2014 Deferred tax asset: Basis difference in stock of company $ 0.5 $ — $ — $ — Total deferred tax asset 0.5 — — — Deferred tax liability: Basis difference in stock of acquired company (8.9 ) (12.0 ) (0.4 ) (0.7 ) Total deferred tax liability (8.9 ) (12.0 ) (0.4 ) (0.7 ) Net deferred tax liability $ (8.4 ) $ (12.0 ) $ (0.4 ) $ (0.7 ) Uncertain Tax Positions.

Partners' Capital

Partners' Capital	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Equity [Abstract]
Partners' Capital	Note 9 – Partners’ Capital Distributions Crestwood Equity Limited Partners. Record Date Payment Date Per Cash (in millions) 2016 February 5, 2016 February 12, 2016 $ 1.375 $ 95.6 2015 February 6, 2015 February 13, 2015 $ 1.375 $ 25.8 On April 21, 2016, we declared a distribution of $0.60 per limited partner unit to be paid on May 13, 2016, to unitholders of record on May 6, 2016 with respect to the first quarter of 2016. Preferred Unit Holders . Crestwood Midstream Prior to the Simplification Merger, the Company indirectly owned a non-economic general partnership interest in Crestwood Midstream and 100% of its incentive distribution rights (IDRs). Crestwood Midstream was also a publicly-traded limited partnership with common units listed on the NYSE. However, as a result of Crestwood Midstream’s completion of the Simplification Merger on September 30, 2015, its common units ceased to be listed on the NYSE, the IDRs were eliminated and Crestwood Midstream became a wholly-owned subsidiary of the Company. During the three months ended March 31, 2016 and 2015, Crestwood Midstream made distributions of $97.2 million and $26.6 million to Crestwood Equity. During the three months ended March 31, 2015, Crestwood Midstream paid a cash distribution to its general partner (representing IDRs and distributions related to common units held by the general partner) of approximately $10.5 million. Limited Partners Record Date Payment Date Per Cash (in millions) February 6, 2015 February 13, 2015 $ 0.41 $ 74.3 Non-Controlling Partners Crestwood Midstream Class A Preferred Units As discussed, in conjunction with the closing of the Simplification Merger, the CMLP Class A Preferred Units were exchanged for new preferred units of Crestwood Equity. Prior to the Simplification Merger, Crestwood Equity classified the CMLP Class A Preferred Units as a component of Interest of Non-Controlling Partners on its consolidated balance sheet. Crestwood Niobrara Preferred Interest Crestwood Niobrara issued a preferred interest 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. Net Income (Loss) Attributable to Non-Controlling Partners The components of net income (loss) attributable to non-controlling partners for the three months ended March 31, 2016 and 2015, are as follows (in millions) Three Months Ended 2016 2015 Crestwood Niobrara preferred interests $ 5.9 $ 5.6 CMLP net income attributable to non-controlling partners 5.9 5.6 Crestwood Midstream limited partner interests — (5.0 ) Crestwood Midstream Class A preferred units — 9.2 CEQP net income attributable to non-controlling partners $ 5.9 $ 9.8 Distributions to Non-Controlling Partners Crestwood Midstream Limited Partners. Crestwood Midstream Class A Preferred Unit Holders Crestwood Niobrara Preferred Unit Holders.	Note 12—Partners’ Capital Simplification 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. Immediately following the Simplification Merger and the transactions described above, as of December 31, 2015, CEQP owns a 99.9% limited partnership interest in Crestwood Midstream and CEQP’s wholly-owned subsidiary, CGS GP, owns a 0.1% limited partnership interest in Crestwood Midstream. Common Units Historically, Crestwood Midstream periodically sold common units in public offerings to generate funds to reduce the indebtedness under its credit facility and to fund acquisitions. The table below presents limited partner unit issuances by Legacy Crestwood, Inergy Midstream and Crestwood Midstream. Issuer Issuance Date Units Per Unit Gross Price Per Unit Net Price (1) Net Proceeds (in millions) Legacy Crestwood March 22, 2013 5,175,000 (2) 23.90 23.00 118.5 Inergy Midstream September 13, 2013 11,773,191 (3) 22.50 21.69 255.2 Crestwood Midstream October 23, 2013 16,100,000 (4) N/A 21.19 340.3 (1) Price is net of underwriting discounts. (2) Includes 675,000 units that were issued in April 2013. (3) Includes 773,191 units that were issued on October 7, 2013. (4) Includes 2,100,000 units that were issued on October 30, 2013. During 2013, Legacy Crestwood issued Class D units representing limited partner units. Legacy Crestwood had the option to pay distributions to its Class D unitholders with cash or by issuing additional paid-in-kind units based upon the volume common unit weighted-average price for 10 trading days immediately preceding the date the distribution was declared. On April 1, 2013, the outstanding Legacy Crestwood Class C units converted to common units on a one-for-one basis. In conjunction with the Crestwood Merger, Legacy Crestwood unitholders received 1.07 units of Inergy Midstream units for each unit of Legacy Crestwood they owned and as a result, there were no common or Class D units outstanding immediately following the Crestwood Merger. During 2013, Legacy Crestwood issued 183,995 and 292,660 additional Class C and Class D units in lieu of paying a quarterly cash distribution. Preferred Units On June 17, 2014, Crestwood Midstream entered into definitive agreements with a group of investors, including Magnetar Financial, affiliates of GSO Capital Partners LP and GE Energy Financial Services (the Class A Purchasers). Under these agreements, Crestwood Midstream agreed to sell to the Class A Purchasers and the Class A Purchasers have 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. Through December 31, 2014, the Class A Purchasers purchased 17,529,879 CMLP Preferred Units for a cash purchase price of $25.10 per unit resulting in gross proceeds to us of approximately $440.0 million (net proceeds of approximately $430.5 million after deducting transaction fees and offering expenses). On August 10, 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 Crestwood Equity Partners LP partners’ capital on its consolidated balance sheet as of December 31, 2015. Prior to the Simplification Merger, Crestwood Equity classified the CMLP Preferred Units as a component of Interest of Non-Controlling Partners on its consolidated balance sheet. 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 after June 17, 2017, 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. Distributions Crestwood Equity Description • 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. Working capital borrowings are generally borrowings that are made under CEQP’s working capital facility and in all cases are used solely for working capital purposes or to pay distributions to partners. 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, 2015, 2014 and 2013 is presented below: Record Date Payment Date Per Unit Rate Cash Distributions (in millions) 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 2014 February 7, 2014 February 14, 2014 $ 1.375 $ 25.6 May 8, 2014 May 15, 2014 $ 1.375 25.7 August 7, 2014 August 14, 2014 $ 1.375 25.6 November 7, 2014 November 14, 2014 $ 1.375 25.6 $ 102.5 2013 August 7, 2013 August 14, 2013 $ 1.30 $ 22.3 November 7, 2013 November 14, 2013 $ 1.35 25.0 $ 47.3 On February 12, 2016, we paid a distribution of $1.3750 per limited partner unit to unitholders of record on February 5, 2016 with respect to the fourth quarter of 2015. Preferred Unit Holders . During the year ended December 31, 2015, we issued 1,372,573 Preferred Units to our preferred unit holders in lieu of paying a quarterly cash distribution of $12.5 million. On February 12, 2016, we issued 1,404,317 Preferred Units to our preferred unit holders for the quarter ended December 31, 2015 in lieu of paying a cash distribution of $12.8 million. Crestwood Midstream Description Following the Crestwood Merger and 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 On September 30, 2015, Crestwood Midstream made a distribution of approximately $378.3 million to CEQP for purposes of repaying (or, if applicable, satisfying and discharging) substantially all of its outstanding indebtedness. The distribution was funded with borrowings under the Crestwood Midstream credit facility. In addition, during the years ended December 31, 2015, 2014 and 2013, Crestwood Midstream made distributions of $175.6 million, $101.6 million and $50.0 million, which represented net amounts due to Crestwood Midstream related to cash advances to CEQP for its general corporate activities. As discussed in Note 6, in December 2014, Crestwood Midstream paid approximately $66.4 million to acquire a 50.01% in Tres Palacios from Crestwood Equity. Crestwood Midstream reflected the difference between the cash paid in excess of Crestwood Equity’s basis of approximately $30.6 million as a distribution to its general partner on its consolidated statement of partners’ capital and its consolidated statement of cash flows for the year ended December 31, 2014. Limited Partners 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 2014 February 7, 2014 February 14, 2014 $ 0.41 $ 74.1 May 8, 2014 May 15, 2014 $ 0.41 74.2 August 7, 2014 August 14, 2014 $ 0.41 74.1 November 7, 2014 November 14, 2014 $ 0.41 74.1 $ 296.5 2013 January 31, 2013 February 12, 2013 $ 0.510 $ 21.0 April 30, 2013 May 10, 2013 $ 0.510 27.4 August 1, 2013 August 9, 2013 $ 0.510 27.4 August 7, 2013(1) August 14, 2013 $ 0.400 34.3 November 7, 2013 (1) November 14, 2013 $ 0.405 69.5 $ 179.6 (1) Represents distributions associated with Inergy Midstream limited partner units. Class A Preferred Unit Holders 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 on its consolidated balance sheet. Crestwood Niobrara Preferred Interest Crestwood Niobrara issued a preferred interest 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. The preferred interest is reflected as non-controlling interest in Crestwood Equity’s and Crestwood Midstream’s consolidated financial statements. We serve as the managing member of Crestwood Niobrara and, subject to certain restrictions, we have the ability to redeem GE’s preferred interest in either cash or common units at an amount equal to the face amount of the preferred units plus an applicable return. Pursuant to Crestwood Niobrara’s agreement with GE, GE made capital contributions to Crestwood Niobrara in exchange for an equivalent number of preferred units. During the years ended December 31, 2014 and 2013, GE made capital contributions of $53.9 million and $96.1 million to Crestwood Niobrara. As of December 31, 2014, GE has fulfilled its capital contribution commitment to Crestwood Niobrara of $150.0 million and is no longer required to make quarterly contributions to Crestwood Niobrara. 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, 2015, 2014 and 2013 are as follows (in millions) Year Ended December 31, 2015 2014 2013 Crestwood Niobrara preferred interests $ 23.1 $ 16.8 $ 4.9 CMLP net income attributable to non-controlling partners 23.1 16.8 4.9 Crestwood Midstream limited partner interests (683.0 ) (100.8 ) (62.2 ) Crestwood Midstream Class A preferred units 23.1 17.2 — CEQP net income (loss) attributable to non-controlling partners $ (636.8 ) $ (66.8 ) $ (57.3 ) Distributions to Non-Controlling Partners Crestwood Midstream Limited Partners Crestwood Midstream Class A Preferred Unitholders Crestwood Niobrara Preferred Unitholders Other Partners’ Capital Transactions Crestwood Merger 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. As discussed in Note 1, in conjunction with the Crestwood Merger, Legacy Crestwood unitholders received 1.07 units of Inergy Midstream units for each Legacy Crestwood unit they owned and as a result, there were no Legacy Crestwood common or Class D units outstanding immediately following the merger. In addition, Legacy Crestwood unitholders also received a $34.9 million distribution, $10 million of which was funded as a non-cash contribution from Crestwood Holdings and is reflected on Crestwood Equity’s consolidated statements of partners’ capital as contribution from Crestwood Holding LLC for the year ended December 31, 2013. Crestwood Equity reflected the distribution of $34.9 million as distributions to non-controlling partners on its consolidated statements of partners’ capital for the year ended December 31, 2013. Crestwood Midstream reflected the $10 million non-cash contribution from Crestwood Holdings as contributions from general partner on its consolidated statement of partners’ capital for the year ended December 31, 2013. In addition, Crestwood Midstream reflected the distribution of $34.9 million as distribution to partners on its consolidated statements of partners’ capital for the year ended December 31, 2013. In conjunction with the Crestwood Merger, the restricted units outstanding under the Legacy Inergy long-term incentive plan were modified to accelerate the vesting of certain outstanding awards on December 31, 2013. Crestwood Equity reflected the cash paid of approximately $11.8 million related to these vested units as distributions to partners on its consolidated statement of cash flows for the year ended December 31, 2013. Following the closing of the Crestwood Merger, Crestwood Holdings exchanged 7,100,000 common units of CMLP for 14,300,000 common units of CEQP pursuant to an option obtained on June 19, 2013 when it acquired CEQP’s general partner. This exchange resulted in a $182.3 million decrease to the interest of non-controlling partners and a$182.3 million increase to partners’ capital on Crestwood Equity’s consolidated statement of partners’ capital for the year ended December 31, 2013. Acquisitions Crestwood Marcellus Midstream LLC (CMM). Arrow.

Equity Plans

Equity Plans	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Equity Plans	Note 13—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 and Crestwood Midstream’s common unitholders and to provide an incentive for continuous employment. Long-term incentive compensation consist of grants of restricted and phantom units which vest based upon continued service. Prior to the completion of the Simplification Merger, Crestwood Midstream also granted incentive awards under is Long-term Incentive Plan (Crestwood Midstream LTIP). In conjunction with the closing of the Simplification Merger, the restricted and phantom common units granted under the Crestwood Midstream LTIP were converted into restricted and phantom units of CEQP with substantially the same terms considering the 2.75 to 1 exchange ratio. Crestwood LTIP The following table summarizes information regarding restricted and phantom unit activity during the years ended December 31, 2015 and 2014. As discussed in Note 10, the board of directors of CEQP’s general partner approved a 1-for-10 reverse split of our common units effective November 23, 2015. The restricted and phantom units in the table below have been recast to reflect the reverse split. Units Weighted-Average Grant Unvested—January 1, 2014 49,354 $ 139.60 Vested—restricted units (44,993 ) $ 139.70 Granted—restricted units 137,746 $ 132.30 Forfeited (10,519 ) $ 137.30 Unvested—December 31, 2014 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 (1) We implemented a company-wide initiative to reduce operating costs in 2015 and beyond, which included a reduction in work force. As a result, 7,263 restricted units were forfeited during the year ended December 31, 2015. As of December 31, 2015 and 2014, we had total unamortized compensation expense of approximately $16.5 million and $8.1 million related to restricted and phantom units, which we expect 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 $11.5 million, $10.1 million and $10.9 million under the Crestwood LTIP during the years ended December 31, 2015, 2014 and 2013, which is included in general and administrative expenses on our consolidated statements of operations. As of February 12, 2016, we had 5,978,939 units available for issuance under the Crestwood LTIP. Crestwood Restricted Units. Crestwood Phantom Units. Crestwood Midstream The following table summarizes information regarding restricted and phantom unit activity during the years ended December 31, 2015 and 2014: Units Weighted-Average Grant Unvested—January 1, 2014 250,557 $ 22.13 Vested—restricted units (208,361 ) $ 22.15 Granted—restricted units 871,078 $ 23.25 Forfeited (78,478 ) $ 23.33 Unvested—December 31, 2014 834,796 $ 23.18 Vested—restricted units (457,458 ) $ 22.91 Vested—phantom units (21,578 ) $ 16.05 Granted—restricted units 535,858 $ 15.89 Granted—phantom units 171,648 $ 15.76 Modification—restricted units (823,277 ) $ 20.06 Modification—phantom units (150,070 ) $ 18.93 Forfeited (1) (89,919 ) $ 16.05 Unvested—December 31, 2015 — $ — (1) We implemented a company-wide initiative to reduce operating costs in 2015 and beyond, which included a reduction in work force. As a result, 39,172 restricted units were forfeited during the year ended December 31, 2015. As of December 31, 2014, we had total unamortized compensation expense of approximately $9.5 million related to restricted and phantom units issued under the Crestwood Midstream LTIP. Crestwood Midstream recognized compensation expense of approximately $8.1 million, $11.2 million and $11.4 million (including $6.5 million recognized by Legacy Crestwood in 2013 as discussed below) during the years ended December 31, 2015, 2014 and 2013, which is included in general and administrative expenses on our consolidated statements of operations. As of December 31, 2015, we do not have any issued, outstanding units available for issuance under the Crestwood Midstream LTIP. Crestwood Midstream Restricted Units. Crestwood Midstream Phantom Units. Crestwood Midstream Employee Unit Purchase Plan Crestwood Midstream had an employee unit purchase plan under which employees of the general partner purchased Crestwood Midstream’s common units through payroll deductions up to a maximum of 10% of the employees’ eligible compensation. Under the plan, Crestwood Midstream purchased its common units on the open market for the benefit of participating employees based on their payroll deductions. In addition, Crestwood Midstream could contribute an additional 10% of participating employees’ payroll deductions to purchase additional Crestwood Midstream common units for participating employees. Unless increased by the board of directors of Crestwood Midstream’s general partner, the maximum number of units that were available for purchase under the plan was 200,000. Effective May 7, 2015, Crestwood Midstream suspended the employee unit purchase plan. In conjunction with the Simplification Merger, all common units purchased through the employee purchase plan were converted into common units of CEQP. Legacy Crestwood Prior to the Crestwood Merger, Legacy Crestwood issued phantom units under its Fourth Amended and Restated 2007 Equity Plan (2007 Equity Plan). The 2007 Equity Plan was terminated in conjunction with the Crestwood Merger. Crestwood Midstream recognized compensation expense under the 2007 Equity Plan of approximately $6.5 million for the year ended December 31, 2013.

Employee Benefit Plan

Employee Benefit Plan	12 Months Ended
	Dec. 31, 2015
Postemployment Benefits [Abstract]
Employee Benefit Plan	Note 14—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 2015 and $17,500 in 2014 and 2013. 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 $0.5 million during the years ended December 31, 2015, 2014 and 2013.

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 10 – Commitments and Contingencies Legal Proceedings Canadian Class Action Lawsuit. In March 2014, the plaintiffs filed their fourth amended motion to name Arrow and numerous other energy companies as additional defendants in the class action lawsuit. The plaintiffs alleged, among other things, that Arrow (i) was a producer of the crude oil being transported on the derailed train, (ii) was negligent in failing to properly classify the crude delivered to the trucks that hauled the crude to the rail loading terminal, and (iii) owed a duty to the petitioners to ensure the safe transportation of the crude being transported. The motion to authorize the class action and motions in opposition were heard by the Court in June 2014. In June 2015, the Superior Court determined that the Class Action Suit proceeding should be allowed to proceed against certain respondents that have not contributed to the global settlement described below. Because Arrow is a contributing party to the global settlement, the Class Action Suit against Arrow has been stayed pending finalization of the global settlement plan in the United States and Canadian bankruptcy proceedings described below. One of the defendants in the lawsuit, Montreal Main & Atlantic Railway (MM&A), filed bankruptcy actions in the U.S. Bankruptcy Court for the District of Maine and in the Canadian Bankruptcy Court. The bankruptcy trustees in the proceedings approached the respondents in the Class Action Suit (including Arrow) to contribute monetary damages to a global settlement for all claims, including any potential environmental damages, related to the Lac Megantic derailment. During the first quarter of 2015, Crestwood Midstream agreed to contribute to the global settlement in exchange for a release from all claims related to the derailment, including the Class Action Suit. In June 2015, the creditors in the Canadian bankruptcy proceeding voted unanimously in favor of the global settlement. The Canadian bankruptcy court approved the bankruptcy plan (including the global settlement) on July 13, 2015, and the United States bankruptcy court approved a modified version of the bankruptcy plan (including the global settlement) on October 9, 2015. Consistent with the modified plan approved in the US bankruptcy proceeding, the Canadian bankruptcy court also approved a modified bankruptcy plan on October 9, 2015. The US and Canadian bankruptcy proceedings were finalized in December 2015 and the funding of the settlement was complete. Crestwood Midstream’s contribution to the global settlement, in addition to associated legal fees, is fully covered by insurance, and since the global settlement is finalized, Arrow should not be exposed to additional damages relating to the derailment. Additional lawsuits related to the derailment were filed and are pending in United States courts. However, all of lawsuits have been stayed as a result of the automatic stay arising from MM&A’s United States bankruptcy proceeding. Arrow has been named as a defendant in 39 lawsuits pending in three different courts; however, we expect these lawsuits to be dismissed with prejudice upon disbursement of funds to the victims. An order of dismissal has been signed by the judge. If an appeal of the order of dismissal is not filed by May 6, 2016, these cases will be dismissed. Based on Crestwood Midstream’s contribution to the global settlement and since the global settlement was approved by both bankruptcy courts, we do not anticipate any material loss in this matter after considering insurance. Simplification Merger Lawsuits Lawrence G. Farber, individually and on behalf of all others similarly situated v. Crestwood Midstream Partners LP, Crestwood Midstream GP LLC, Robert G. Phillips, Alvin Bledsoe, Michael G. France, Philip D. Gettig, Warren H. Gfellar, David Lumpkins, John J. Sherman, David Wood, Crestwood Equity Partners LP, Crestwood Equity GP LLC, CEQP ST Sub LLC, MGP GP, LLC, Crestwood Midstream Holdings LP, and Crestwood Gas Services GP LLC On July 21, 2015, Isaac Aron, another purported unitholder of the Crestwood Midstream, filed a complaint in the Southern District of the United States, Houston Division, as a putative class action on behalf of Crestwood Midstream’s unitholders, entitled Isaac Aron, individually and on behalf of all others similarly situated vs. Robert G. Phillps, Alvin Bledsoe, Michael G. France, Philip D. Getting, Warren H. Gfeller, David Lumpkins, John J. Sherman, David Wood, Crestwood Midstream Partners, LP Crestwood Midstream Holdings LP, Crestwood Midstream GP LLC, Crestwood Gas Services GP, LLC, Crestwood Equity Partners LP, Crestwood Equity GP LLC, CEQP ST Sub LLC and MGP GP, LLC. On August 12, 2015, the defendants filed a motion to consolidate the Farber and Aron cases, which the court granted on September 4, 2015. Farber subsequently dismissed his claims against all the defendants on September 16, 2015. Aron filed a motion for temporary restraining order and requested an expedited preliminary injunction hearing, which had been scheduled for September 23, 2015. On September 22, 2015, however, the parties entered into a memorandum of understanding (MOU) with respect to a proposed settlement of the Aron lawsuit. The settlement contemplated by the MOU is subject to a number of conditions, including notice to the class, limited confirmatory discovery and final court approval of the settlement. The defendants expect the court to approve the final settlement during the first half of 2016. The anticipated settlement of the MOU has not and will not have a material impact to our consolidated financial statements. Property Taxes. General. 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 its results of operations, cash flows or financial condition. Environmental Compliance 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, and thereafter contained and cleaned up the releases completely 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. 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 March 31, 2016. We may potentially be subject to fines and penalties as a result of the water releases. In October 2014, we received data requests from the Environmental Protection Agency (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 have commenced settlement discussions with the EPA concerning the NOPV. 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, and we provided the requested information during the second quarter of 2015. 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 ongoing settlement discussions with the regulatory agencies asserting jurisdiction over the 2014 produced water releases. We cannot predict what the outcome of these investigations will be. Our operations are subject to stringent and complex laws and regulations pertaining to health, safety, and the environment. We are subject to laws and regulations at the federal, state and local levels that relate to air and water quality, hazardous and solid waste management and disposal and other environmental matters. The cost of planning, designing, constructing and operating our facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures. At March 31, 2016 and December 31, 2015, our accrual of approximately $1.7 million was primarily related to the Arrow water releases described above, which 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 $1.7 million to $3.5 million. 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. At March 31, 2016 and December 31, 2015, CEQP’s self-insurance reserves were $17.8 million and $17.2 million. We estimate that $11.3 million of this balance will be paid subsequent to March 31, 2017. As such, CEQP has classified $11.3 million in other long-term liabilities on its consolidated balance sheet at March 31, 2016. At March 31, 2016 and December 31, 2015, CMLP’s self insurance reserves were $12.3 million and $11.4 million. CMLP estimates that $7.1 million of this balance will be paid subsequent to March 31, 2017. As such, CMLP has classified $7.1 million in other long-term liabilities on its consolidated balance sheet at March 31, 2016.	Note 15—Commitments and Contingencies Legal Proceedings Canadian Class Action Lawsuit. In March 2014, the plaintiffs filed their fourth amended motion to name Arrow and numerous other energy companies as additional defendants in the class action lawsuit. The plaintiffs alleged, among other things, that Arrow (i) was a producer of the crude oil being transported on the derailed train, (ii) was negligent in failing to properly classify the crude delivered to the trucks that hauled the crude to the rail loading terminal, and (iii) owed a duty to the petitioners to ensure the safe transportation of the crude being transported. The motion to authorize the class action and motions in opposition were heard by the Court in June 2014. In June 2015, the Superior Court determined that the Class Action Suit proceeding should be allowed to proceed against certain respondents that have not contributed to the global settlement described below. Because Arrow is a contributing party to the global settlement, the Class Action Suit against Arrow has been stayed pending finalization of the global settlement plan in the United States and Canadian bankruptcy proceedings described below. One of the defendants in the lawsuit, Montreal Main & Atlantic Railway (MM&A), filed bankruptcy actions in the U.S. Bankruptcy Court for the District of Maine and in the Canadian Bankruptcy Court. The bankruptcy trustees in the proceedings approached the respondents in the Class Action Suit (including Arrow) to contribute monetary damages to a global settlement for all claims, including any potential environmental damages, related to the Lac Megantic derailment. During the first quarter of 2015, Crestwood Midstream agreed to contribute to the global settlement in exchange for a release from all claims related to the derailment, including the Class Action Suit. In June 2015, the creditors in the Canadian bankruptcy proceeding voted unanimously in favor of the global settlement. The Canadian bankruptcy court approved the bankruptcy plan (including the global settlement) on July 13, 2015, and the United States bankruptcy court approved a modified version of the bankruptcy plan (including the global settlement) on October 9, 2015. Consistent with the modified plan approved in the US bankruptcy proceeding, the Canadian bankruptcy court also approved a modified bankruptcy plan on October 9, 2015. The US and Canadian bankruptcy proceedings were finalized in December 2015 and the funding of the settlement was complete. Crestwood Midstream’s contribution to the global settlement, in addition to associated legal fees, is fully covered by insurance, and since the global settlement is finalized, Arrow should not be exposed to additional damages relating to the derailment. Additional lawsuits related to the derailment were filed and are pending in United States courts, however, all of lawsuits have been stayed as a result of the automatic stay arising from MM&A’s United States bankruptcy proceeding. Arrow has been named as a defendant in 39 lawsuits pending in three different courts; however, we expect these lawsuits to be dismissed with prejudice upon disbursement of funds to the victims. We expect these cases to be dismissed by the end of April 2016. Based on Crestwood Midstream’s contribution to the global settlement and since the global settlement was approved by both bankruptcy courts, we do not anticipate any material loss in this matter after considering insurance. Simplification Merger Lawsuits Lawrence G. Farber, individually and on behalf of all others similarly situated v. Crestwood Midstream Partners LP, Crestwood Midstream GP LLC, Robert G. Phillips, Alvin Bledsoe, Michael G. France, Philip D. Gettig, Warren H. Gfellar, David Lumpkins, John J. Sherman, David Wood, Crestwood Equity Partners LP, Crestwood Equity GP LLC, CEQP ST Sub LLC, MGP GP, LLC, Crestwood Midstream Holdings LP, and Crestwood Gas Services GP LLC On July 21, 2015, Isaac Aron, another purported unitholder of the Crestwood Midstream, filed a complaint in the Southern District of the United States, Houston Division, as a putative class action on behalf of Crestwood Midstream’s unitholders, entitled Isaac Aron, individually and on behalf of all others similarly situated vs. Robert G. Phillps, Alvin Bledsoe, Michael G. France, Philip D. Getting, Warren H. Gfeller, David Lumpkins, John J. Sherman, David Wood, Crestwood Midstream Partners, LP Crestwood Midstream Holdings LP, Crestwood Midstream GP LLC, Crestwood Gas Services GP, LLC, Crestwood Equity Partners LP, Crestwood Equity GP LLC, CEQP ST Sub LLC and MGP GP, LLC. On August 12, 2015, the defendants filed a motion to consolidate the Farber and Aron cases, which the court granted on September 4, 2015. Farber subsequently dismissed his claims against all the defendants on September 16, 2015. Aron filed a motion for temporary restraining order and requested an expedited preliminary injunction hearing, which was scheduled for September 23, 2015. On September 22, 2015, the parties entered into a memorandum of understanding (MOU) with respect to a proposed settlement of the Aron lawsuit. The settlement contemplated by the MOU is subject to a number of conditions, including notice to the class, limited confirmatory discovery and final court approval of the settlement. The defendants expect the court to approve the final settlement during the first half of 2016. The anticipated settlement of the MOU has not and will not have a material impact to our consolidated financial statements. Property Taxes. General 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 its results of operations, cash flows or financial condition. Environmental Compliance During the year ended December 31, 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, and thereafter contained and cleaned up the releases completely 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 release. 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, 2015. We may potentially be subject to fines and penalties as a result of the water releases. In October 2014, we received data requests from the Environmental Protection Agency (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 have commenced settlement discussions with the EPA concerning the NOPV. 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, and we provided the requested information during the second quarter of 2015. 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 ongoing settlement discussions with the regulatory agencies asserting jurisdiction over the 2014 produced water releases. We cannot predict what the outcome of these investigations will be. Our operations are subject to stringent and complex laws and regulations pertaining to health, safety, and the environment. We are subject to laws and regulations at the federal, state and local levels that relate to air and water quality, hazardous and solid waste management and disposal and other environmental matters. The cost of planning, designing, constructing and operating our facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures. At December 31, 2015 and 2014, our accrual of approximately $1.7 million and $1.1 million was primarily related to the Arrow water releases described above, which 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 $1.7 million to $3.7 million. 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 evaluates our insurance accruals and adjusts 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, 2015 and 2014, CEQP’s self-insurance reserves were $17.2 millionand $14.6 million. CEQP estimates that $11.3 million of this balance will be paid subsequent to December 31, 2016. As such, CEQP has classified $11.3 million in other long-term liabilities on our consolidated balance sheets. At December 31, 2015 and 2014, CMLP’s self-insurance reserves were $11.4 million and $7.2 million. CMLP estimates that $7.1 million of this balance will be paid subsequent to December 31, 2016. As such, CMLP has classified $7.1 million in other long-term liabilities on our consolidated balance sheets. Contingent Consideration—Antero In connection with the acquisition of Antero Resources Appalachian Corporation (Antero), we agreed to pay Antero conditional consideration in the form of potential additional cash payments of up to $40.0 million, depending on the achievement of certain defined average annual production levels achieved during 2012, 2013 and 2014. In February 2015, we paid Antero $40.0 million to settle the liability under the earn-out provision. This amount is reflected in changes in operating assets and liabilities, net of effects from acquisitions under operating activities in our consolidated statements of cash flows. Commitments and Purchase Obligations 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, 2016 $ 19.1 2017 16.6 2018 15.3 2019 14.1 2020 9.2 Thereafter 23.8 Total minimum lease payments $ 98.1 Our rent expense for operating leases for the years ended December 31, 2015, 2014 and 2013, totaled $37.4 million, $41.8 million and $16.4 million. Purchase Commitments. We have entered into certain purchase commitments in connection with the identified growth projects and maintenance obligations primarily related to our gathering and processing segment, the development of a rail terminal project and certain upgrades to the US Salt facility. At December 31, 2015, the total of our storage and transportation and marketing, supply and logistics operations’ firm purchase commitments was approximately $12.7 million and our gathering and processing segment’s purchase commitments totaled approximately $13.5 million. The majority of the purchases associated with these commitments are expected to occur over the next twelve months.

Related Party Transactions

Related Party Transactions	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Related Party Transactions [Abstract]
Related Party Transactions	Note 11 – Related Party Transactions CEQP and CMLP enter into transactions with their 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. The following table shows revenues, costs of product/services sold, general and administrative expenses and reimbursements of expenses from our affiliates for the three months ended March 31, 2016 and 2015 ( in millions Three Months Ended 2016 2015 Gathering and processing revenues at CEQP and CMLP $ 0.7 $ 1.0 Gathering and processing costs of product/services sold at CEQP and CMLP (1) $ 4.3 $ 8.3 Operations and maintenance expenses charged at CEQP and CMLP $ 0.7 $ 0.9 General and administrative expenses charged by CEQP to CMLP, net (2) $ 3.7 $ 17.4 General and administrative expenses charged by CEQP to Crestwood Holdings, net (3) $ 0.1 $ 0.1 (1) Represents natural gas purchases from Sabine Oil and Gas Corporation. (2) Includes $4.5 million and $2.2 million of net unit-based compensation charges allocated from CEQP to CMLP for three months ended March 31, 2016 and 2015. In addition, prior to the completion of the Simplification Merger, CEQP allocated general and administrative costs to CMLP. In conjunction with the Simplification Merger, CMLP shares common management, general and administrative and overhead costs with CEQP. During the three months ended March 31, 2016, CMLP allocated $0.8 million of general and administrative costs to CEQP. (3) Includes less than $0.1 million unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the three months ended 2016. The following table shows accounts receivable and accounts payable from our affiliates as of March 31, 2016 and December 31, 2015 ( in millions CEQP CMLP March 31, 2016 December 31, 2015 March 31, 2016 December 31, 2015 Accounts receivable $ 1.1 $ 1.7 $ 1.1 $ 1.7 Accounts payable $ 3.8 $ 4.0 $ 1.3 $ 1.5	Note 16—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, including Sabine Oil and Gas LLC and Mountaineer Keystone LLC. CEQP and CMLP enter into transactions with their 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. As discussed in Note 1, in conjunction with the completion of the Simplification Merger, CEQP contributed 100% of its interest in Crestwood Operations to CMLP. Crestwood Operations has 1,288 full-time employees as of December 31, 2015, 297 of which are general and administrative employees and 991 of which are operational employees. Prior to the Simplification Merger, CMLP did not have any employees other than approximately 100 union employees of US Salt. CMLP shares common management, general and administrative and overhead costs with CEQP and allocated shared costs of $0.8 million to CEQP during the year ended December 31, 2015. 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, 2015, 2014 and 2013 ( in millions Year Ended December 31, 2015 2014 2013 Gathering and processing revenues at CEQP and CMLP $ 3.9 $ 3.0 $ 74.9 Gathering and processing costs of product/services sold at CEQP and CMLP (1) $ 28.9 $ 42.2 $ 32.5 Operations and maintenance expenses charged at CEQP and CMLP $ 2.8 $ 0.2 $ — General and administrative expenses charged by CEQP to CMLP, net (2) $ 49.5 $ 63.6 $ 34.7 General and administrative expenses charged by CEQP to Crestwood Holdings, net (3) $ 0.4 $ 0.5 $ 25.3 (1) Represents natural gas purchases from Sabine Oil and Gas. (2) Includes $10.0 million, $6.9 million and $4.4 million of net unit-based compensation charges allocated from CEQP to CMLP for the years ended December 31, 2015, 2014 and 2013. (3) Includes $0.1 million unit-based compensation charges allocated from Crestwood Holdings to CMLP during the year ended December 31, 2015. The following table shows accounts receivable and accounts payable from our affiliates as of December 31, 2015 and 2014 ( in millions CEQP CMLP December 31, December 31, 2015 2014 2015 2014 Accounts receivable $ 1.7 $ 0.6 $ 1.7 $ 0.3 Accounts payable $ 4.0 $ 5.6 $ 1.5 $ 3.1

Segments

Segments	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Segment Reporting [Abstract]
Segments	Note 12 – Segments Financial Information As discussed in Note 1, on September 30, 2015, the Company contributed 100% of its interest in Crestwood Operations to Crestwood Midstream and as a result, we modified our segments and our financial statements to reflect three operating and reportable segments: (i) gathering and processing operations; (ii) storage and transportation operations; and (iii) marketing, supply and logistics operations (formerly NGL and crude services operations). Consequently, the results of our Arrow operations are now reflected in our gathering and processing operations for all periods presented and our COLT and PRBIC operations are now reflected in our storage and transportation operations for all periods presented. These respective operations were previously included in our NGL and crude services 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, a non-GAAP financial measure, which is defined as income before income taxes, plus debt-related costs (net interest and debt expense) and depreciation, amortization and accretion expense. Below is a reconciliation of CEQP’s net income to EBITDA ( in millions Three Months Ended March 31, 2016 2015 Net income (loss) $ (93.7 ) $ 18.1 Add: Interest and debt expense, net 36.1 33.6 Provision for income taxes — 0.4 Depreciation, amortization and accretion 62.3 74.2 EBITDA $ 4.7 $ 126.3 The following tables summarize CEQP’s reportable segment data for the three months ended March 31, 2016 and 2015 ( in millions Three Months Ended March 31, 2016 Gathering and Storage and Marketing, Supply and Corporate Total Revenues $ 238.9 $ 59.4 $ 237.7 $ — $ 536.0 Intersegment revenues 20.5 0.4 (20.9 ) — — Costs of product/services sold 179.8 2.9 180.7 — 363.4 Operations and maintenance expense 17.8 7.2 16.8 — 41.8 General and administrative expense — — — 23.0 23.0 Goodwill impairment (8.6 ) (13.7 ) (87.4 ) — (109.7 ) Earnings from unconsolidated affiliates, net 5.1 1.4 — — 6.5 Other income, net — — — 0.1 0.1 EBITDA $ 58.3 $ 37.4 $ (68.1 ) $ (22.9 ) $ 4.7 Goodwill $ 45.9 $ 757.5 $ 172.4 $ — $ 975.8 Total assets $ 2,321.2 $ 2,185.7 $ 924.4 $ 138.7 $ 5,570.0 Purchases of property, plant and equipment $ 44.3 $ 3.3 $ 7.1 $ 0.9 $ 55.6 Three Months Ended March 31, 2015 Gathering and Processing Storage and Marketing, Supply and Logistics Corporate Total Revenues $ 350.3 $ 67.6 $ 313.6 $ — $ 731.5 Intersegment revenues 10.1 — (10.1 ) — — Costs of product/services sold 266.7 5.3 257.7 — 529.7 Operations and maintenance expense 24.1 6.4 20.1 — 50.6 General and administrative expense — — — 27.5 27.5 Loss on long-lived assets (0.3 ) (0.7 ) — — (1.0 ) Earnings from unconsolidated affiliates, net 2.5 0.9 — — 3.4 Other income, net — — — 0.2 0.2 EBITDA $ 71.8 $ 56.1 $ 25.7 $ (27.3 ) $ 126.3 Purchases of property, plant and equipment $ 36.2 $ 4.1 $ 6.9 $ 0.2 $ 47.4 Below is a reconciliation of CMLP’s net income to EBITDA ( in millions Three Months Ended 2016 2015 Net income (loss) $ (95.3 ) $ 29.1 Add: Interest and debt expense, net 36.1 29.9 Provision (benefit) for income taxes (0.2 ) 0.4 Depreciation, amortization and accretion 64.9 68.8 EBITDA $ 5.5 $ 128.2 The following tables summarize CMLP’s reportable segment data for the three months ended March 31, 2016 and 2015 ( in millions Three Months Ended March 31, 2016 Gathering and Storage and Marketing, Supply and Corporate Total Revenues $ 238.9 $ 59.4 $ 237.7 $ — $ 536.0 Intersegment revenues 20.5 0.4 (20.9 ) — — Costs of product/services sold 179.8 2.9 180.7 — 363.4 Operations and maintenance expense 17.8 7.1 16.8 — 41.7 General and administrative expense — — — 22.2 22.2 Goodwill impairment (8.6 ) (13.7 ) (87.4 ) — (109.7 ) Earnings from unconsolidated affiliates, net 5.1 1.4 — — 6.5 EBITDA $ 58.3 $ 37.5 $ (68.1 ) $ (22.2 ) $ 5.5 Goodwill $ 45.9 $ 757.5 $ 172.4 $ — $ 975.8 Total assets $ 2,534.1 $ 2,185.0 $ 924.4 $ 123.9 $ 5,767.4 Purchases of property, plant and equipment $ 44.3 $ 3.3 $ 7.1 $ 0.9 $ 55.6 Three Months Ended March 31, 2015 Gathering and Storage and Marketing, Supply and Corporate Total Revenues $ 350.3 $ 67.6 $ 313.6 $ — $ 731.5 Intersegment revenues 10.1 — (10.1 ) — — Costs of product/services sold 266.7 5.3 257.7 — 529.7 Operations and maintenance expense 24.1 6.4 20.1 — 50.6 General and administrative expense — — — 25.6 25.6 Loss on long-lived assets (0.3 ) (0.5 ) — — (0.8 ) Earnings from unconsolidated affiliates, net 2.5 0.9 — — 3.4 EBITDA $ 71.8 $ 56.3 $ 25.7 $ (25.6 ) $ 128.2 Purchases of property, plant and equipment $ 36.2 $ 4.1 $ 6.9 $ 0.2 $ 47.4	Note 17—Segments Financial Information As discussed in Note 1, on September 30, 2015, the Company contributed 100% of its interest in Crestwood Operations to Crestwood Midstream and as a result, we modified our segments and our financial statements now reflect three operating and reportable segments: (i) gathering and processing operations; (ii) storage and transportation operations; and (iii) marketing, supply and logistics operations (formerly NGL and crude services operations). Consequently, the results of our Arrow operations are now reflected in our gathering and processing operations for all periods presented and our COLT and PRBIC operations are now reflected in our storage and transportation operations for all periods presented. These respective operations were previously included in our NGL and crude services 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 loss on modification/extinguishment of debt) and depreciation, amortization and accretion expense. Below is a reconciliation of CEQP’s net income to EBITDA ( in millions Year Ended December 31, 2015 2014 2013 Net loss $ (2,303.7 ) $ (10.4 ) $ (50.6 ) Add: Interest and debt expense, net 140.1 127.1 77.9 Loss on modification/extinguishment of debt 20.0 — — Provision (benefit) for income taxes (1.4 ) 1.1 1.0 Depreciation, amortization and accretion 300.1 285.3 167.9 EBITDA $ (1,844.9 ) $ 403.1 $ 196.2 The following tables summarize CEQP’s reportable segment data for the years ended December 31, 2015, 2014 and 2013 ( in millions Year Ended December 31, 2015 Gathering and Storage and Marketing, 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, net (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 ) Goodwill $ 54.5 $ 771.2 $ 259.8 $ — $ 1,085.5 Total assets $ 2,325.2 $ 2,217.4 $ 1,083.7 $ 177.4 $ 5,803.7 Purchases of property, plant and equipment $ 132.7 $ 26.4 $ 22.8 $ 0.8 $ 182.7 Year Ended December 31, 2014 Gathering and Storage and Marketing, Corporate Total Revenues $ 2,166.8 $ 264.6 $ 1,499.9 $ — $ 3,931.3 Intersegment revenues 50.0 — (50.0 ) — — Costs of product/services sold 1,859.9 33.3 1,272.1 — 3,165.3 Operations and maintenance expense 102.8 28.8 71.7 — 203.3 General and administrative expense — — — 100.2 100.2 Gain (loss) on long-lived assets (32.7 ) 33.8 (3.0 ) — (1.9 ) Goodwill impairment (18.5 ) — (30.3 ) — (48.8 ) Loss on contingent consideration (8.6 ) — — — (8.6 ) Earnings (loss) from unconsolidated affiliates 0.5 (1.2 ) — — (0.7 ) Other income, net — — — 0.6 0.6 EBITDA $ 194.8 $ 235.1 $ 72.8 $ (99.6 ) $ 403.1 Goodwill $ 384.2 $ 1,394.6 $ 713.0 $ — $ 2,491.8 Total assets $ 3,593.6 $ 2,423.3 $ 2,240.6 $ 203.9 $ 8,461.4 Purchases of property, plant and equipment $ 327.9 $ 37.0 $ 50.9 $ 8.2 $ 424.0 Year Ended December 31, 2013 Gathering and Storage and Marketing, Corporate Total Revenues $ 510.0 $ 130.9 $ 785.8 $ — $ 1,426.7 Costs of product/services sold 267.5 19.7 715.1 — 1,002.3 Operations and maintenance expense 58.7 14.2 31.7 — 104.6 General and administrative expense — — — 93.5 93.5 Gain (loss) on long-lived assets 5.4 — (0.1 ) — 5.3 Goodwill impairment (4.1 ) — — — (4.1 ) Gain on contingent consideration (31.4 ) — — — (31.4 ) Earnings (loss) from unconsolidated affiliates 0.1 (0.2 ) — — (0.1 ) Other income, net — — — 0.2 0.2 EBITDA $ 153.8 $ 96.8 $ 38.9 $ (93.3 ) $ 196.2 Purchases of property, plant and equipment $ 290.7 $ 43.4 $ 11.9 $ 1.0 $ 347.0 Below is a reconciliation of CMLP’s net income to EBITDA ( in millions Year Ended December 31, 2015 2014 2013 Net income (loss) $ (1,410.6 ) $ 14.7 $ (12.4 ) Add: Interest and debt expense, net 130.5 111.4 71.7 Loss on modification/extinguishment of debt 18.9 — — Provision for income taxes — 0.9 0.7 Depreciation, amortization and accretion 278.5 255.4 139.4 EBITDA $ (982.7 ) $ 382.4 $ 199.4 The following tables summarize CMLP’s reportable segment data for the years ended December 31, 2015, 2014 and 2013 ( in millions Year Ended December 31, 2015 Gathering and Storage and Marketing, 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 ) Goodwill $ 54.5 $ 771.2 $ 259.8 $ — $ 1,085.5 Total assets $ 2,541.6 $ 2,216.7 $ 1,083.7 $ 162.5 $ 6,004.5 Purchases of property, plant and equipment $ 132.7 $ 26.4 $ 22.8 $ 0.8 $ 182.7 Year Ended December 31, 2014 Gathering and Storage and Marketing, Corporate Total Revenues $ 2,166.8 $ 250.8 $ 1,499.9 $ — $ 3,917.5 Intersegment revenues 50.0 — (50.0 ) — — Costs of product/services sold 1,859.9 22.8 1,272.1 — 3,154.8 Operations and maintenance expense 102.8 22.1 70.5 — 195.4 General and administrative expense — — — 91.7 91.7 Gain (loss) on long-lived assets, net (32.7 ) 0.6 (3.0 ) — (35.1 ) Goodwill impairment (18.5 ) — (30.3 ) — (48.8 ) Loss on contingent consideration (8.6 ) — — — (8.6 ) Earnings (loss) from unconsolidated affiliates, net 0.5 (1.2 ) — — (0.7 ) EBITDA $ 194.8 $ 205.3 $ 74.0 $ (91.7 ) $ 382.4 Goodwill $ 127.0 $ 1,394.6 $ 713.0 $ — $ 2,234.6 Total assets $ 2,941.6 $ 2,423.3 $ 2,240.6 $ 179.7 $ 7,785.2 Purchases of property, plant and equipment $ 327.9 $ 36.4 $ 50.9 $ 6.5 $ 421.7 Year Ended December 31, 2013 Gathering and Storage and Marketing, Corporate Total Revenues $ 510.0 $ 116.8 $ 785.8 $ — $ 1,412.6 Costs of product/services sold 267.5 12.8 715.1 — 995.4 Operations and maintenance expense 58.7 12.4 32.3 — 103.4 General and administrative expense — — — 84.1 84.1 Gain on long-lived assets 5.4 — (0.1 ) — 5.3 Goodwill impairment (4.1 ) — — — (4.1 ) Loss on contingent consideration (31.4 ) — — — (31.4 ) Earnings (loss) from unconsolidated affiliates, net 0.1 (0.2 ) — — (0.1 ) EBITDA $ 153.8 $ 91.4 $ 38.3 $ (84.1 ) $ 199.4 Purchases of property, plant and equipment $ 290.7 $ 35.7 $ 11.9 $ 1.0 $ 339.3 Major Customers No customer accounted for 10% or more of our total consolidated revenues for the years ended December 31, 2015 and 2013 at CEQP or CMLP. For the year ended December 31, 2014, we had revenues from Tesoro Corporation (Tesoro) of $465.2 million which exceeded 10% of the total consolidated revenues at CEQP and CMLP. Revenues from Tesoro are reflected in each of our reportable segments.

Condensed Consolidating Financi

Condensed Consolidating Financial Information	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Text Block [Abstract]
Condensed Consolidating Financial Information	Note 13 – Condensed Consolidating Financial Information Crestwood Midstream is a holding company and own no operating assets and have no significant operations independent of its subsidiaries (Parent). 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 Niobrara, 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 March 31, 2016 and December 31, 2015, and for the three months ended March 31, 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 March 31, 2016 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Assets Current assets: Cash $ 0.8 $ — $ — $ — $ 0.8 Accounts receivable — 209.1 0.5 — 209.6 Inventory — 26.6 — — 26.6 Other current assets — 33.3 — — 33.3 Total current assets 0.8 269.0 0.5 — 270.3 Property, plant and equipment, net — 3,514.4 — — 3,514.4 Goodwill and intangible assets, net — 1,719.1 — — 1,719.1 Investment in consolidated affiliates 5,350.2 — — (5,350.2 ) — Investment in unconsolidated affiliates — — 260.6 — 260.6 Other assets — 3.0 — — 3.0 Total assets $ 5,351.0 $ 5,505.5 $ 261.1 $ (5,350.2 ) $ 5,767.4 Liabilities and partners’ capital Current liabilities: Accounts payable $ — $ 116.5 $ — $ — $ 116.5 Other current liabilities 35.8 67.0 — — 102.8 Total current liabilities 35.8 183.5 — — 219.3 Long-term liabilities: Long-term debt, less current portion 2,528.2 2.6 — — 2,530.8 Other long-term liabilities — 44.1 — — 44.1 Deferred income taxes — 0.6 — — 0.6 Partners’ capital 2,787.0 5,274.7 75.5 (5,350.2 ) 2,787.0 Interest of non-controlling partners in subsidiaries — — 185.6 — 185.6 Total partners’ capital 2,787.0 5,274.7 261.1 (5,350.2 ) 2,972.6 Total liabilities and partners’ capital $ 5,351.0 $ 5,505.5 $ 261.1 $ (5,350.2 ) $ 5,767.4 Crestwood Midstream Partners LP Condensed Consolidating Balance Sheet December 31, 2015 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Assets Current assets: Cash $ 0.1 $ — $ — $ — $ 0.1 Accounts receivable — 236.0 0.5 — 236.5 Inventory — 44.5 — — 44.5 Other current assets — 52.5 — — 52.5 Total current assets 0.1 333.0 0.5 — 333.6 Property, plant and equipment, net — 3,525.7 — — 3,525.7 Goodwill and intangible assets, net — 1,846.9 — — 1,846.9 Investment in consolidated affiliates 5,506.8 — — (5,506.8 ) — Investment in unconsolidated affiliates — — 254.3 — 254.3 Other assets — 3.1 — — 3.1 Total assets $ 5,506.9 $ 5,708.7 $ 254.8 $ (5,506.8 ) $ 5,963.6 Liabilities and partners’ capital Current liabilities: Accounts payable $ — $ 141.3 $ 0.1 $ — $ 141.4 Other current liabilities 26.4 85.2 — — 111.6 Total current liabilities 26.4 226.5 0.1 — 253.0 Long-term liabilities: Long-term debt, less current portion 2,498.9 2.9 — — 2,501.8 Other long-term liabilities — 43.3 — — 43.3 Deferred income taxes — 0.4 — — 0.4 Partners’ capital 2,981.6 5,435.6 71.2 (5,506.8 ) 2,981.6 Interest of non-controlling partners in subsidiaries — — 183.5 — 183.5 Total partners’ capital 2,981.6 5,435.6 254.7 (5,506.8 ) 3,165.1 Total liabilities and partners’ capital $ 5,506.9 $ 5,708.7 $ 254.8 $ (5,506.8 ) $ 5,963.6 Crestwood Midstream Partners LP Condensed Consolidating Statement of Operations Three Months Ended March 31, 2016 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Revenues $ — $ 536.0 $ — $ — $ 536.0 Costs of product/services sold — 363.4 — — 363.4 Expenses: Operations and maintenance — 41.7 — — 41.7 General and administrative 17.7 4.5 — — 22.2 Depreciation, amortization and accretion — 64.9 — — 64.9 17.7 111.1 — — 128.8 Other operating expense: Goodwill impairment — (109.7 ) — — (109.7 ) Operating loss (17.7 ) (48.2 ) — — (65.9 ) Earnings from unconsolidated affiliates, net — — 6.5 — 6.5 Interest and debt expense, net (36.1 ) — — — (36.1 ) Equity in net income (loss) of subsidiary (41.5 ) — — 41.5 — Income (loss) before income taxes (95.3 ) (48.2 ) 6.5 41.5 (95.5 ) Benefit for income taxes — (0.2 ) — — (0.2 ) Net income (loss) (95.3 ) (48.0 ) 6.5 41.5 (95.3 ) Net income attributable to non-controlling partners in subsidiaries — — 5.9 — 5.9 Net income (loss) attributable to Crestwood Midstream Partners LP $ (95.3 ) $ (48.0 ) $ 0.6 $ 41.5 $ (101.2 ) Crestwood Midstream Partners LP Condensed Consolidating Statement of Operations Three Months Ended March 31, 2015 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Revenues $ — $ 731.5 $ — $ — $ 731.5 Costs of product/services sold — 529.7 — — 529.7 Expenses: Operations and maintenance — 50.6 — — 50.6 General and administrative 13.4 12.2 — — 25.6 Depreciation, amortization and accretion 0.2 68.6 — — 68.8 13.6 131.4 — — 145.0 Other operating expense: Loss on long-lived assets, net — (0.8 ) — — (0.8 ) Operating income (loss) (13.6 ) 69.6 — — 56.0 Earnings from unconsolidated affiliates, net — — 3.4 — 3.4 Interest and debt expense, net (29.9 ) — — — (29.9 ) Equity in net income (loss) of subsidiary 72.6 — — (72.6 ) — Income (loss) before income taxes 29.1 69.6 3.4 (72.6 ) 29.5 Provision for income taxes — 0.4 — — 0.4 Net income (loss) 29.1 69.2 3.4 (72.6 ) 29.1 Net income attributable to non-controlling partners in subsidiaries — — 5.6 — 5.6 Net income (loss) attributable to Crestwood Midstream Partners LP 29.1 69.2 (2.2 ) (72.6 ) 23.5 Net income attributable to Class A preferred units 9.2 — — — 9.2 Net income (loss) attributable to partners $ 19.9 $ 69.2 $ (2.2 ) $ (72.6 ) $ 14.3 Crestwood Midstream Partners LP Condensed Consolidating Statement of Cash Flows Three Months Ended March 31, 2016 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Cash flows from operating activities: $ (42.7 ) $ 172.8 $ 5.6 $ — $ 135.7 Cash flows from investing activities: Purchases of property, plant and equipment (0.9 ) (54.7 ) — — (55.6 ) Investment in unconsolidated affiliates — — (5.5 ) — (5.5 ) Proceeds from the sale of assets — 0.8 — — 0.8 Capital contributions to consolidated affiliates (3.7 ) — — 3.7 — Net cash provided by (used in) investing activities (4.6 ) (53.9 ) (5.5 ) 3.7 (60.3 ) Cash flows from financing activities: Proceeds from the issuance of long-term debt 313.5 — — — 313.5 Principal payments on long-term debt (286.0 ) — — — (286.0 ) Payments on capital leases — (0.5 ) — — (0.5 ) Payments for debt-related deferred costs (0.1 ) — — — (0.1 ) Distributions paid (97.2 ) — (3.8 ) — (101.0 ) Contributions from parent — — 3.7 (3.7 ) — Taxes paid for unit-based compensation vesting — (0.6 ) — — (0.6 ) Change in intercompany balances 117.8 (117.8 ) — — — Net cash provided by (used in) financing activities 48.0 (118.9 ) (0.1 ) (3.7 ) (74.7 ) Net change in cash 0.7 — — — 0.7 Cash at beginning of period 0.1 — — — 0.1 Cash at end of period $ 0.8 $ — $ — $ — $ 0.8 Crestwood Midstream Partners LP Condensed Consolidating Statement of Cash Flows Three Months Ended March 31, 2015 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Cash flows from operating activities: $ (54.8 ) $ 160.5 $ — $ — $ 105.7 Cash flows from investing activities: Purchases of property, plant and equipment (0.1 ) (47.3 ) — — (47.4 ) Investment in unconsolidated affiliates — — (17.9 ) — (17.9 ) Proceeds from the sale of assets — 0.5 — — 0.5 Capital contributions to consolidated affiliates (17.9 ) — — 17.9 — Other — (0.2 ) — — (0.2 ) Net cash provided by (used in) investing activities (18.0 ) (47.0 ) (17.9 ) 17.9 (65.0 ) Cash flows from financing activities: Proceeds from the issuance of long-term debt 1,114.6 — — — 1,114.6 Principal payments on long-term debt (970.4 ) — — — (970.4 ) Payments on capital leases (0.5 ) (0.2 ) — — (0.7 ) Payments for debt-related deferred costs (11.1 ) — — — (11.1 ) Distributions paid (111.4 ) — — — (111.4 ) Contributions from parent — — 17.9 (17.9 ) — Taxes paid for unit-based compensation vesting — (1.7 ) — — (1.7 ) Change in intercompany balances 51.8 (51.8 ) — — — Other (0.2 ) — — — (0.2 ) Net cash provided by (used in) financing activities 72.8 (53.7 ) 17.9 (17.9 ) 19.1 Net change in cash — 59.8 — — 59.8 Cash at beginning of period — 7.6 — — 7.6 Cash at end of period $ — $ 67.4 $ — $ — $ 67.4	Note 18—Crestwood Midstream Condensed Consolidating Financial Information Crestwood Midstream is a holding company and own no operating assets and have no significant operations independent of its subsidiaries (Parent). 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 Niobrara, 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. At December 31, 2014, we reflected the interest of non-controlling partners in subsidiaries on our condensed consolidating balance sheet as a component of the Parent’s and Non-Guarantor Subsidiaries’ total partners’ capital, with an adjustment to eliminate the Parent’s portion. During the year ended December 31, 2015, we began reflecting the interest of non-controlling partners in subsidiaries as a component of the Non-Guarantor Subsidiaries’ total partners’ capital only. The condensed consolidating balance sheet for the year December 31, 2014 was adjusted to reflect the change in presentation and there was no impact to our consolidated balance sheet. 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, 2015, 2014 and 2013. 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, 2015 (in millions) Parent Guarantor Subsidiaries Non- Eliminations Consolidated Assets Current assets: Cash $ 0.1 $ — $ — $ — $ 0.1 Accounts receivable — 236.0 0.5 — 236.5 Inventory — 44.5 — — 44.5 Other current assets — 52.5 — — 52.5 Total current assets 0.1 333.0 0.5 — 333.6 Property, plant and equipment, net — 3,525.7 — — 3,525.7 Goodwill and intangible assets, net 40.9 1,846.9 — — 1,887.8 Investment in consolidated affiliates 5,506.8 — — (5,506.8 ) — Investment in unconsolidated affiliates — — 254.3 — 254.3 Other assets — 3.1 — — 3.1 Total assets $ 5,547.8 $ 5,708.7 $ 254.8 $ (5,506.8 ) $ 6,004.5 Liabilities and partners’ capital Current liabilities: Accounts payable — 141.3 0.1 — 141.4 Other current liabilities 26.4 85.2 — — 111.6 Total current liabilities 26.4 226.5 0.1 — 253.0 Long-term liabilities: Long-term debt, less current portion 2,539.8 2.9 — — 2,542.7 Other long-term liabilities — 43.3 — — 43.3 Deferred income taxes — 0.4 — — 0.4 Partners’ capital 2,981.6 5,435.6 71.2 (5,506.8 ) 2,981.6 Interest of non-controlling partners in subsidiaries — — 183.5 — 183.5 Total partners’ capital 2,981.6 5,435.6 254.7 (5,506.8 ) 3,165.1 Total liabilities and partners’ capital $ 5,547.8 $ 5,708.7 $ 254.8 $ (5,506.8 ) $ 6,004.5 Crestwood Midstream Partners LP Condensed Consolidating Balance Sheet December 31, 2014 (in millions) Parent Guarantor Non- Eliminations Consolidated Assets Current assets: Cash $ — $ 7.6 $ — $ — $ 7.6 Accounts receivable 1.2 377.8 0.3 — 379.3 Inventory — 46.6 — — 46.6 Other current assets — 103.1 — 103.1 Total current assets 1.2 535.1 0.3 — 536.6 Property, plant and equipment, net 7.9 3,738.1 — — 3,746.0 Goodwill and intangible assets, net 38.0 3,166.2 — — 3,204.2 Investment in consolidated affiliates 7,148.0 — — (7,148.0 ) — Investment in unconsolidated affiliates — — 295.1 — 295.1 Other assets — 3.3 — — 3.3 Total assets $ 7,195.1 $ 7,442.7 $ 295.4 $ (7,148.0 ) $ 7,785.2 Liabilities and partners’ capital Current liabilities: Accounts payable 9.0 225.8 0.2 — 235.0 Other current liabilities 23.0 153.3 — — 176.3 Total current liabilities 32.0 379.1 0.2 — 411.3 Long-term liabilities: Long-term debt, less current portion 2,012.8 1.7 — — 2,014.5 Other long-term liabilities 1.6 36.7 — — 38.3 Deferred income taxes — 0.7 — — 0.7 Partners’ capital 5,148.7 7,024.5 123.5 (7,148.0 ) 5,148.7 Interest of non-controlling partners in subsidiaries — — 171.7 — 171.7 Total partners’ capital 5,148.7 7,024.5 295.2 (7,148.0 ) 5,320.4 Total liabilities and partners’ capital $ 7,195.1 $ 7,442.7 $ 295.4 $ (7,148.0 ) $ 7,785.2 Crestwood Midstream Partners LP Condensed Consolidating Statements of Operations Year Ended December 31, 2015 (in millions) Parent Guarantor Non- 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 expense: 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 subsidiary (1,195.9 ) — — 1,195.9 — Income (loss) before income taxes (1,410.6 ) (1,135.1 ) (60.8 ) 1,195.9 (1,410.6 ) Provision for income taxes — — — — — Net income (loss) (1,410.6 ) (1,135.1 ) (60.8 ) 1,195.9 (1,410.6 ) Net income attributable to non-controlling partners in subsidiaries — — (23.1 ) — (23.1 ) Net income (loss) attributable to Crestwood Midstream Partners LP (1,410.6 ) (1,135.1 ) (83.9 ) 1,195.9 (1,433.7 ) Net income attributable to Class A preferred units (23.1 ) — — — (23.1 ) Net income (loss) attributable to partners $ (1,433.7 ) $ (1,135.1 ) $ (83.9 ) $ 1,195.9 $ (1,456.8 ) Crestwood Midstream Partners LP Condensed Consolidating Statements of Operations Year Ended December 31, 2014 (in millions) Parent Guarantor Non- Eliminations Consolidated Revenues $ — $ 3,917.5 $ — $ — $ 3,917.5 Costs of product/services sold — 3,154.8 — — 3,154.8 Expenses: Operations and maintenance — 195.4 — — 195.4 General and administrative 49.4 42.3 — — 91.7 Depreciation, amortization and accretion 0.9 254.5 — — 255.4 50.3 492.2 — — 542.5 Other operating expense: Loss on long-lived assets, net — (35.1 ) — — (35.1 ) Goodwill impairment — (48.8 ) — — (48.8 ) Loss on contingent consideration — (8.6 ) — — (8.6 ) Operating income (loss) (50.3 ) 178.0 — — 127.7 Loss from unconsolidated affiliates, net — — (0.7 ) — (0.7 ) Interest and debt expense, net (111.4 ) — — — (111.4 ) Equity in net income (loss) of subsidiary 176.4 — — (176.4 ) — Income (loss) before income taxes 14.7 178.0 (0.7 ) (176.4 ) 15.6 Provision for income taxes — 0.9 — 0.9 Net income (loss) 14.7 177.1 (0.7 ) (176.4 ) 14.7 Net income attributable to non-controlling partners — — (16.8 ) — (16.8 ) Net income (loss) attributable to Crestwood Midstream Partners LP 14.7 177.1 (17.5 ) (176.4 ) (2.1 ) Net income attributable to Class A preferred units (17.2 ) — — — (17.2 ) Net income (loss) attributable to partners $ (2.5 ) $ 177.1 $ (17.5 ) $ (176.4 ) $ (19.3 ) Crestwood Midstream Partners Condensed Consolidating Statements of Operations Year Ended December 31, 2013 (in millions) Parent Guarantor Non- Eliminations Consolidated Revenues $ — $ 1,412.6 $ — $ — $ 1,412.6 Costs of product/services sold — 995.4 — — 995.4 Expenses: Operations and maintenance — 103.4 — — 103.4 General and administrative 46.5 37.6 — — 84.1 Depreciation, amortization and accretion 1.0 138.4 — — 139.4 47.5 279.4 — — 326.9 Other operating income (expense): Gain on long-lived assets, net — 5.3 — — 5.3 Goodwill impairment — (4.1 ) — — (4.1 ) Loss on contingent consideration — (31.4 ) — — (31.4 ) Operating income (loss) (47.5 ) 107.6 — — 60.1 Loss from unconsolidated affiliates, net — — (0.1 ) — (0.1 ) Interest and debt expense, net (68.7 ) (3.0 ) — — (71.7 ) Equity in net income (loss) of subsidiary 103.8 — — (103.8 ) — Income (loss) before income taxes (12.4 ) 104.6 (0.1 ) (103.8 ) (11.7 ) Provision for income taxes — 0.7 — — 0.7 Net income (loss) (12.4 ) 103.9 (0.1 ) (103.8 ) (12.4 ) Net income attributable to non-controlling partners — — (4.9 ) — (4.9 ) Net income (loss) attributable to Crestwood Midstream Partners LP (12.4 ) 103.9 (5.0 ) (103.8 ) (17.3 ) Net income attributable to Class A preferred units — — — — — Net income (loss) attributable to partners $ (12.4 ) $ 103.9 $ (5.0 ) $ (103.8 ) $ (17.3 ) Crestwood Midstream Partners LP Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2015 (in millions) Parent Guarantor Non- 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 ) Proceeds from the sale of assets — 2.7 — — 2.7 Capital distributions from unconsolidated affiliates — — 9.3 — 9.3 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 Principal 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 paid (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 Crestwood Midstream Partners LP Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2014 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Cash flows from operating activities: $ (165.6 ) $ 602.9 $ — $ — $ 437.3 Cash flows from investing activities: Acquisitions, net of cash acquired — (19.5 ) — — (19.5 ) Purchases of property, plant and equipment (4.3 ) (417.4 ) — — (421.7 ) Investment in unconsolidated affiliates, net — — (144.4 ) — (144.4 ) Proceeds from the sale of assets — 2.7 — — 2.7 Capital contributions to consolidated affiliates (89.5 ) — — 89.5 — Net cash provided by (used in) investing activities (93.8 ) (434.2 ) (144.4 ) 89.5 (582.9 ) Cash flows from financing activities: Proceeds from the issuance of long-term debt 2,089.9 — — — 2,089.9 Principal payments on long-term debt (1,949.8 ) (0.2 ) — — (1,950.0 ) Payments on capital leases (1.3 ) (1.9 ) — — (3.2 ) Payments for debt-related deferred costs (0.1 ) — — — (0.1 ) Distributions paid (470.5 ) — — — (470.5 ) Contributions from parents — — 89.5 (89.5 ) — Net proceeds from issuance of preferred equity of subsidiary — — 53.9 — 53.9 Net proceeds from issuance of Class A preferred units 430.5 — — — 430.5 Taxes paid for unit-based compensation vesting — (1.6 ) — — (1.6 ) Change in intercompany balances 161.4 (161.4 ) — — — Other (0.8 ) — — — (0.8 ) Net cash provided by (used in) financing activities 259.3 (165.1 ) 143.4 (89.5 ) 148.1 Net change in cash (0.1 ) 3.6 (1.0 ) — 2.5 Cash at beginning of period 0.1 4.0 1.0 — 5.1 Cash at end of period $ — $ 7.6 $ — $ — $ 7.6 Crestwood Midstream Partners LP Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2013 (in millions) Parent Guarantor Non- Eliminations Consolidated Cash flows from operating activities: $ (46.1 ) $ 333.6 $ — $ (33.8 ) $ 253.7 Cash flows from investing activities: Acquisitions, net of cash acquired — (561.5 ) — — (561.5 ) Purchases of property, plant and equipment (1.0 ) (338.3 ) — — (339.3 ) Investment in unconsolidated affiliates, net — — (151.5 ) — (151.5 ) Capital contributions to consolidated affiliates (106.4 ) — — 106.4 — Proceeds from the sale of assets — 11.2 — — 11.2 Net cash provided by (used in) investing activities (107.4 ) (888.6 ) (151.5 ) 106.4 (1,041.1 ) Cash flows from financing activities: Proceeds from the issuance of long-term debt 2,072.8 — — — 2,072.8 Principal payments on long-term debt (1,634.3 ) (0.2 ) — — (1,634.5 ) Payments on capital leases (0.4 ) (3.9 ) — — (4.3 ) Payments for debt-related deferred costs (32.0 ) — — — (32.0 ) Distributions paid (419.7 ) (33.8 ) — 33.8 (419.7 ) Contributions from parents — 55.5 56.4 (106.4 ) 5.5 Net proceeds from the issuance of common units 714.0 — — — 714.0 Net proceeds from issuance of preferred equity of subsidiary — — 96.1 — 96.1 Taxes paid for unit-based compensation vesting — (5.5 ) — — (5.5 ) Change in intercompany balances (546.8 ) 546.8 — — — Net cash provided by (used in) financing activities 153.6 558.9 152.5 (72.6 ) 792.4 Net change in cash 0.1 3.9 1.0 — 5.0 Cash at beginning of period — 0.1 — — 0.1 Cash at end of period $ 0.1 $ 4.0 $ 1.0 $ — $ 5.1

Supplemental Selected Quarterly

Supplemental Selected Quarterly Financial Information (Unaudited)	12 Months Ended
	Dec. 31, 2015
Text Block [Abstract]
Supplemental Selected Quarterly Financial Information (Unaudited)	Supplemental Selected Quarterly Financial Information (Unaudited) Summarized unaudited quarterly financial data is presented below ( in millions, except per unit information Crestwood Equity Quarter Ended March 31 June 30 September 30 December 31 2015 Revenues $ 731.5 $ 641.5 $ 630.7 $ 629.1 Operating income (loss) (1) 48.5 (248.9 ) (588.3 ) (1,296.1 ) Earnings (loss) from unconsolidated affiliates, net 3.4 5.0 2.8 (72.0 ) Net income (loss) 18.1 (296.0 ) (623.4 ) (1,402.4 ) Net income (loss) attributable to partners 8.3 (40.0 ) (226.9 ) (1,414.5 ) Net income (loss) per limited partner unit: Basic $ 0.44 $ (2.14 ) $ (11.78 ) $ (20.77 ) Diluted $ 0.44 $ (2.14 ) $ (11.76 ) $ (20.77 ) 2014 Revenues $ 971.6 $ 926.3 $ 1,036.2 $ 997.2 Operating income (loss) (1) 45.7 29.4 43.0 (0.2 ) Earnings (loss) from unconsolidated affiliates, net (0.1 ) (1.5 ) 0.3 0.6 Net income (loss) 13.2 (4.8 ) 11.9 (30.7 ) Net income (loss) attributable to partners 19.6 (4.4 ) 2.8 38.4 Net income (loss) per limited partner unit: Basic $ 1.05 $ (0.24 ) $ 0.15 $ 2.06 Diluted $ 1.05 $ (0.24 ) $ 0.15 $ 2.06 Crestwood Midstream Quarter Ended March 31 June 30 September 30 December 31 2015 Revenues $ 731.5 $ 641.5 $ 630.7 $ 629.1 Operating income (loss) (2) 56.0 (28.0 ) (578.7 ) (649.7 ) Earnings (loss) from unconsolidated affiliates, net 3.4 5.0 2.8 (72.0 ) Net income (loss) 29.1 (72.8 ) (610.2 ) (756.7 ) Net income (loss) attributable to partners 14.3 (86.0 ) (622.5 ) (762.6 ) 2014 Revenues $ 964.9 $ 923.9 $ 1,033.8 $ 994.9 Operating income (loss) (2) 54.7 41.6 54.6 (23.2 ) Earnings (loss) from unconsolidated affiliates, net (0.1 ) (1.5 ) 0.3 0.6 Net income (loss) 25.8 11.0 27.1 (49.2 ) Net income (loss) attributable to partners 22.7 6.2 13.5 (61.7 ) (1) Amount includes goodwill, property, plant and equipment and intangible asset impairments of approximately $281.0 million, $610.8 million, $1,332.3 million and $83.3 million during the three months ended June 30, 2015, September 30, 2015, December 31, 2015 and December 31, 2014, respectively. See Note 2 for a further discussion of our impairments recorded during 2015 and 2014. In addition, for 2014, amount includes a gain of approximately $30.6 million on the sale of our interest in Tres Palacios. See Note 6 for a further discussion of our divestiture of Tres Palacios. (2) Amount for the three months ended December 31, 2015 includes impairments of our Jackalope and PRBIC equity investments of approximately $51.4 million and $23.4 million, respectively. See Note 2 for a further discussion of these impairments recorded during 2015. (3) Amount includes goodwill, property, plant and equipment and intangible asset impairments of approximately $68.6 million, $610.8 million, $694.3 million and $83.3 million during the three months ended June 30, 2015, September 30, 2015, December 31, 2015 and December 31, 2014, respectively. See Note 2 for a further discussion of our impairments recorded during 2015 and 2014.

Schedule I - Crestwood Equity P

Schedule I - Crestwood Equity Partners LP - Parent Only	12 Months Ended
	Dec. 31, 2015
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 Sheet (in millions) December 31, 2015 2014 Assets Current assets: Cash $ 0.4 $ 3.7 Accounts receivable—trade 1.8 — Accounts receivable—intercompany — 3.2 Total current assets 2.2 6.9 Property, plant and equipment, net 1.5 2.5 Intangible assets 7.8 1.7 Investment in subsidiaries 2,757.7 5,799.5 Other assets 3.5 — Total assets $ 2,772.7 $ 5,810.6 Liabilities and partners’ capital Current liabilities: Accounts payable $ 2.6 $ — Accrued expenses 2.3 1.9 Current portion of long-term debt 0.2 3.0 Total current liabilities 5.1 4.9 Long-term debt, less current portion — 380.0 Other long-term liabilities 4.2 12.9 Total partners’ capital 2,763.4 5,412.8 Total liabilities and partners’ capital $ 2,772.7 $ 5,810.6 See accompanying notes. Schedule I Crestwood Equity Partners LP Parent Only Condensed Statement of Operations (in millions) Year Ended December 31, 2015 2014 2013 Revenues $ — $ — $ — Expenses 14.5 8.5 — Operating loss (14.5 ) (8.5 ) — Interest and debt expense, net (9.6 ) (15.7 ) (6.5 ) Equity in net income (loss) of subsidiaries (2,279.1 ) 14.2 (43.9 ) Loss on modification/extinguishment of debt (1.1 ) — — Other income, net 0.6 — — Loss before income taxes (2,303.7 ) (10.0 ) (50.4 ) Provision for income taxes — 0.4 0.2 Net loss and net loss attributable to Crestwood Equity Partners LP (2,303.7 ) (10.4 ) $ (50.6 ) Net income attributable to preferred units (6.2 ) — — Net loss attributable to partners $ (2,309.9 ) $ (10.4 ) $ (50.6 ) See accompanying notes. Schedule I Crestwood Equity Partners LP Parent Only Condensed Statement of Comprehensive Income (in millions) Year Ended December 31, 2015 2014 2013 Net loss $ (2,303.7 ) $ (10.4 ) $ (50.6 ) Change in fair value of Suburban Propane Partners, LP units (2.7 ) (0.5 ) (0.1 ) Comprehensive loss attributable to Crestwood Equity Partners LP $ (2,306.4 ) $ (10.9 ) $ (50.7 ) See accompanying notes. Schedule I Crestwood Equity Partners LP Parent Only Condensed Statement of Cash Flows (in millions) Year Ended December 31, 2015 2014 2013 Cash flows from operating activities $ (14.7 ) $ (25.3 ) $ (12.3 ) Cash flows from investing activities 593.8 170.8 20.7 Cash flows from financing activities: Proceeds from the issuance of long-term debt 771.7 734.0 394.1 Principal payments on long-term debt (1,152.1 ) (746.2 ) (333.3 ) Payments for debt-related deferred costs — (1.8 ) — Distributions paid to partners (171.5 ) (102.5 ) (68.4 ) Change in intercompany balances (30.5 ) (25.4 ) 0.4 Other — — (1.1 ) Net cash used in financing activities (582.4 ) (141.9 ) (8.3 ) Net change in cash (3.3 ) 3.6 0.1 Cash at beginning of period 3.7 0.1 — Cash at end of period $ 0.4 $ 3.7 $ 0.1 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, 2015, 2014 and 2013, we received cash distributions from Crestwood Midstream Partners LP of approximately $31.4 million, $72.4 million and $26.2 million.

Subsequent Events

Subsequent Events	3 Months Ended
	Mar. 31, 2016
Subsequent Events [Abstract]
Subsequent Events	Note 14 – Subsequent Events In April 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. (Con Edison), entered into a definitive agreement to form a joint venture (the Stagecoach JV) to own and further develop our existing natural gas pipeline and storage business located in southern New York and northern Pennsylvania (the NE S&T assets). Subject to the terms and conditions of the contribution agreement (including customary closing conditions and purchase price adjustments), we will contribute to Stagecoach Gas Services LLC (Stagecoach Gas) the entities owning the NE S&T assets, CEGP will contribute $975 million to Stagecoach Gas in exchange for a 50% equity interest in Stagecoach Gas, and Stagecoach Gas will distribute to Crestwood Northeast the net cash proceeds received from CEGP. The Stagecoach JV transaction is expected to be substantially completed in the second quarter of 2016. In conjunction with our entry into the contribution agreement with CEGP, Crestwood Midstream amended its credit facility in April 2016 to, among other things, (i) facilitate the closing of the joint venture and make investments in the joint venture thereafter, and (ii) implement our liability management plan with the net cash proceeds received from Stagecoach Gas, including the repurchase of Crestwood Midstream’s senior notes with borrowings under its credit facility. The operative terms of the amendment will become effective contemporaneously with the closing of the joint venture. The impact of the transactions discussed above have not been reflected in this Quarterly Report on Form 10-Q as of and for the three months ended March 31, 2016. Detailed descriptions of the contribution agreement and resulting joint venture, as well as the amendment to Crestwood Midstream’s credit facility, are contained in the Form 8-K filed by each of Crestwood Midstream and Crestwood Equity with the SEC on April 22, 2015.

Basis of Presentation and Sum29

Basis of Presentation and Summary of Significant Accounting Policies (Policies)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Accounting Policies [Abstract]
Use of Estimates		Use of Estimates The preparation of our consolidated financial statements in conformity with GAAP requires the use of estimates and assumptions that affect the amounts we report as assets, liabilities, revenues and expenses and our disclosures in these consolidated financial statements. Actual results can differ from those estimates.
Cash		Cash We consider all highly liquid investments with an original maturity of less than three months to be cash.
Inventory		Inventory Inventory for our our storage and transportation operations and our marketing, supply and logistics operations are stated at the lower of cost or market and are computed predominantly using the average cost method. Our inventory consisted primarily of NGLs of approximately $35.4 million and $37.5 million at December 31, 2015 and 2014.
Property, Plant and Equipment		Property, Plant and Equipment Property, plant and equipment is recorded at is original cost of construction or, upon acquisition, at the fair value of the assets acquired. For assets we construct, we capitalize direct costs, such as labor and materials, and indirect costs, such as overhead and interest. We capitalize major units of property replacements or improvement and expense minor items. Depreciation is computed by the straight-line method over the estimated useful lives of the assets, as follows: Years Gathering systems and pipelines 20 Facilities and equipment 20 – 25 Buildings, rights-of-way and easements 20 – 40 Office furniture and fixtures 5 – 10 Vehicles 5 We deplete salt deposits included in our property, plant and equipment utilizing the unit of production method. 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 2015 and 2014, we recorded the following impairments for our property, plant and equipment included in gain (loss) on long-lived assets in our consolidated statements of operations: • During 2015 and 2014, we incurred $8.5 million and $13.2 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 has declared bankruptcy and has ceased any substantial drilling in the Granite Wash in the near future given current and future anticipated market conditions related to normal gas and NGLs. The fair value of our property, plant and equipment related to our Granite Wash operations was $11.2 million as of December 31, 2015. • During 2015, Crestwood Equity incurred $354.4 million of impairments of its property, plant and equipment related to its Barnett gathering and processing operations, which resulted from the recent 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. The fair value of our property, plant and equipment related to our Barnett operations was $298.5 million as of December 31, 2015. • 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. The fair value of our property, plant and equipment related to our Fayetteville and Haynesville operations was $59.3 million and $3.8 million, respectively, as of December 31, 2015. • During 2015, we incurred $31.2 million of impairments on our property, plant and equipment related to our Watkins Glen development project in our marketing, supply and logistics segment, which resulted from continued delays and uncertainties in the permitting of our proposed NGL storage facility. The fair value of our property, plant and equipment related to our Watkins Glen development project was $6.7 million as of December 31, 2015. The remaining carrying value related to the property, plant and equipment associated with these assets represents the fair value of the property, plant and equipment as of December 31, 2015, which is a Level 3 fair value measurement. 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. Projected cash flows of our property, plant and equipment are generally based on current and anticipated future market conditions, which require significant judgment to make projections and assumptions about pricing, demand, competition, operating costs, constructions costs, legal and regulatory issues and other factors that may extend many years into the future and are often outside of our control. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates.
Identifiable Intangible Assets		Identifiable Intangible Assets Our identifiable intangible assets consist of customer accounts, covenants not to compete, trademarks, certain revenue contracts and deferred financing costs. 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. Deferred financing costs represent financing costs incurred in obtaining financing and are being amortized over the term of the related debt using a method which approximates the effective interest method and has a weighted average life of six years. 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 2015 and 2014, we recorded the following impairments of our intangible assets included in gain (loss) on long-lived assets in our consolidated statements of operations: • During 2014, we fully impaired $20 million of intangible assets 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 has declared bankruptcy and has ceased any 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 fully impaired $238.9 million of its intangible assets related to its Barnett gathering and processing operations, which resulted from the recent 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. The remaining carrying value related to these intangible assets represents the fair value of the intangible assets as of December 31, 2015, which is a Level 3 fair value measurement. 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. 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 22 Covenants not to compete 5 Trademarks 6
Goodwill		Goodwill Our goodwill represents the excess of the amount we paid for a business over the fair value of the net identifiable assets acquired. We evaluate goodwill for impairment annually on December 31, and whenever events indicate that it is more likely than not that the fair value of a reporting unit could be less than its carrying amount. This evaluation requires us to compare the fair value of each of our reporting units to its carrying value (including goodwill). If the fair value exceeds the carrying amount, goodwill of the reporting unit is not considered impaired. We estimate the fair value of our reporting units based on a number of factors, including discount rates, projected cash flows and the potential value we would receive if we sold the reporting unit. We also compare the total fair value of our reporting units to our overall enterprise value, which considers the market value for our common and preferred units. Estimating projected cash flows requires us to make certain assumptions as it relates to the future operating performance of each of our reporting units (which includes assumptions, among others, about estimating future operating margins and related future growth in those margins, contracting efforts and the cost and timing of facility expansions) and assumptions related to our customers, such as their future capital and operating plans and their financial condition. When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. If the assumptions embodied in the projections prove inaccurate, we could incur a future impairment charge. 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. Commodity prices have continued to decline since late 2014, and that decline 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 2015 and 2014. The following table summarizes the goodwill of our various reporting units (in millions): Goodwill at Final Goodwill Goodwill at Goodwill (1) Goodwill at Gathering and Processing Fayetteville $ 76.8 $ — $ 4.3 $ 72.5 $ 72.5 $ — Granite Wash 14.2 — 14.2 — — — Marcellus 8.6 — — 8.6 — 8.6 Arrow 45.5 0.4 — 45.9 — 45.9 Storage and Transportation Northeast Storage and Transportation 727.1 (0.8 ) — 726.3 — 726.3 COLT 670.5 (2.2 ) — 668.3 623.4 44.9 Marketing, Supply and Logistics West Coast 89.1 (3.2 ) — 85.9 85.9 — Supply and Logistics 269.5 (3.3 ) — 266.2 99.0 167.2 Storage and Terminals 104.7 (0.5 ) — 104.2 53.7 50.5 US Salt 16.1 (1.3 ) 2.2 12.6 — 12.6 Trucking 178.4 (0.5 ) — 177.9 148.4 29.5 Watkins Glen 94.6 (0.3 ) 28.1 66.2 66.2 — Total Crestwood Midstream $ 2,295.1 $ (11.7 ) $ 48.8 $ 2,234.6 $ 1,149.1 $ 1,085.5 Barnett (Gathering and Processing) 257.2 — — 257.2 257.2 — Total Crestwood Equity $ 2,552.3 $ (11.7 ) $ 48.8 $ 2,491.8 $ 1,406.3 $ 1,085.5 (1) Included in these amounts are approximately $515.4 million and $470.6 million of goodwill impairments recorded at Crestwood Equity and Crestwood Midstream, respectively, during the three months ended December 31, 2015, which primarily resulted from the finalization of the preliminary goodwill impairments recorded on these reporting units during the three months ended September 30, 2015. The goodwill impairments recorded during 2015 and 2014 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 discount rates ranging from 10% to 16% to determine the fair value of our reporting units as of December 31, 2015. The remaining goodwill related to these reporting units represents the fair value of the goodwill as of December 31, 2015, which is a Level 3 fair value measurement.
Investment in Unconsolidated Affiliate		Investment in Unconsolidated Affiliates We evaluate our equity method investments for impairment when events or circumstances indicate that the carrying value of the equity method investment may be impaired and that impairment is other than temporary. If an event occurs, we evaluate the recoverability of our carrying value based on the fair value of the investment. If an impairment is indicated, or if we decide to sell an investment in unconsolidated affiliate, we adjust the carrying values of the asset downward, if necessary, to their estimated fair values. We 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. 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. The remaining carrying value of $202.4 million and $15.1 million related to our Jackalope and PRBIC equity-method investments, respectively, represents the fair value of the equity-method investments as of December 31, 2015, which is a Level 3 fair value measurement.
Asset Retirement Obligations		Asset Retirement Obligations An asset retirement obligation (ARO) is an estimated liability for the cost to retire a tangible asset. We record a liability for legal or contractual obligations to retire our long-lived assets associated with right-of-way contracts we hold and our facilities whether owned or leased. 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, 2015 and 2014, our AROs were reflected in other long-term liabilities on our consolidated balance sheets. See Note 5 for a further discussion of our AROs.
Revenue Recognition		Revenue Recognition We gather, 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 marketing, supply and logistics operations, we take title to the underlying commodity. In the current year, we changed our income statement to classify the revenues associated with the products to which we take title as product revenues in our consolidated statement of operations. In addition, we also reclassified our historical consolidated statements of operations for the years ended December 31,2014 and 2013 to reflect this change. We classify 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, 2015 and 2014, we had deferred revenue of approximately $14.2 million and $12.2 million, which is reflected in accrued expenses and other liabilities on our consolidated balance sheets.
Credit Risk and Concentrations		Credit Risk and Concentrations Inherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate.
Income Taxes		Income Taxes Crestwood Equity is a master limited partnership and Crestwood Midstream is a limited partnership. Partnerships are generally not subject to federal income tax, although publicly-traded partnerships are treated as corporations for federal income tax purposes and therefore are subject to federal income tax, unless the partnership generates at least90% of its gross income from qualifying sources. If the qualifying income requirement is satisfied, the publicly-traded partnership will be treated as a partnership for federal income tax purposes. We satisfy the qualifying income requirement and are treated as a partnership for federal and state income tax purposes. Our consolidated earnings are included in the federal and state income tax returns of our partners. However, legislation in certain states allows for taxation of partnerships, and as such, certain state taxes have been included in our accompanying financial statements as income taxes due to the nature of the tax in those particular states as discussed below. In addition, federal and state income taxes are provided on the earnings of the subsidiaries incorporated as taxable entities. We are required to recognize deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements or tax returns. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial reporting and tax basis of assets and liabilities using expected rates in effect for the year in which the differences are expected to reverse. We are responsible for the Texas Margin tax computed on the Texas franchise tax returns. The margin tax qualifies as an income tax under GAAP, which requires us to recognize the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis attributable to such tax. Net earnings for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax basis and the financial reporting basis of assets and liabilities and the taxable income allocation requirements under the partnership agreement.
Environmental Costs and Other Contingencies		Environmental Costs and Other Contingencies We recognize liabilities for environmental and other contingencies when there is an exposure that indicates it is both probable that a liability has been incurred and the amount of loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue a liability for that amount. Where the most likely outcome cannot be estimated, a range of potential losses is established and if no one amount in that range is more likely than any other, the low end of range is accrued. We record liabilities for environmental contingencies at their undiscounted amounts on our consolidated balance sheets as accrued expenses and other liabilities when environmental assessments indicate that remediation efforts are probable and costs can be reasonably estimated. Estimates of our liabilities are based on currently available facts and presently enacted laws and regulations, taking into consideration the likely effects of other societal and economic factors. These estimates are subject to revision in future periods based on actual costs or new circumstances. We capitalize costs that benefit future periods and recognize a current period charge in operations and maintenance expenses when clean-up efforts do not benefit future periods. We evaluate potential recoveries of amounts from third parties, including insurance coverage, separately from our liability. Recovery is evaluated based on the solvency of the third party, among other factors. When recovery is assured, we record and report an asset separately from the associated liability on our consolidated balance sheet.
Price Risk Management Activities		Price Risk Management Activities We utilize certain derivative financial instruments to (i) manage our exposure to commodity price risk, specifically, the related change in the fair value of inventory, as well as the variability of cash flows related to forecasted transactions; (ii) ensure the availability of adequate physical supply of commodity; and (iii) manage our exposure to the interest rate risk associated with fixed and variable rate borrowings. We record all derivative instruments on the balance sheet at their fair values as either assets or liabilities measured at fair value. Changes in the fair value of these derivative financial instruments are recorded through current earnings. We did not have any derivatives identified as fair value hedges or cash flow hedges for accounting purposes during the years ended December 31, 2015, 2014 or 2013.
Unit-Based Compensation		Unit-Based Compensation Long-term incentive awards are granted under the Crestwood Equity incentive plan. Unit-based compensation awards consist of restricted units that are valued at the closing market price of CEQP’s common units on the date of grant, which reflects the fair value of such awards. For those awards that are settled in cash, the associated liability is remeasured at every balance sheet date through settlement, such that the vested portion of the liability is adjusted to reflect its revised fair value through compensation expense. We generally recognize the expense associated with the award over the vesting period.
Significant Accounting Policies	Significant Accounting Policies There were no material changes in our significant accounting policies from those described in our 2015 Annual Report on Form 10-K. Below is an update of our accounting policies related to Property, Plant and Equipment and Goodwill.
New Accounting Pronouncements Issued But Not Yet Adopted	New Accounting Pronouncements Issued But Not Yet Adopted As of March 31, 2016, the following accounting standards had not yet been adopted by us: In May 2014, the Financial Accounting Standards Board (FASB) issued ASU 2014-09, Revenue from Contracts with Customers, In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) In March 2016, the FASB issued ASU 2016-09, Compensation - Stock Compensation (Topic 718):Improvements to Employee Share-Based Payment Accounting

Basis of Presentation and Sum30

Basis of Presentation and Summary of Significant Accounting Policies (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
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 20 Facilities and equipment 20 – 25 Buildings, rights-of-way and easements 20 – 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 22 Covenants not to compete 5 Trademarks 6
Schedule of Goodwill	The following table summarizes the goodwill of our various reporting units (in millions): Goodwill at December 31, 2015 Goodwill Impairments during the March 31, 2016 Goodwill at March 31, 2016 Gathering and Processing Marcellus $ 8.6 $ 8.6 $ — Arrow 45.9 — 45.9 Storage and Transportation Northeast Storage and Transportation 726.3 — 726.3 COLT 44.9 13.7 31.2 Marketing, Supply and Logistics Supply and Logistics 167.2 65.5 101.7 Storage and Terminals 50.5 14.1 36.4 US Salt 12.6 — 12.6 Trucking 29.5 7.8 21.7 Total $ 1,085.5 $ 109.7 $ 975.8	The following table summarizes the goodwill of our various reporting units (in millions): Goodwill at Final Goodwill Goodwill at Goodwill (1) Goodwill at Gathering and Processing Fayetteville $ 76.8 $ — $ 4.3 $ 72.5 $ 72.5 $ — Granite Wash 14.2 — 14.2 — — — Marcellus 8.6 — — 8.6 — 8.6 Arrow 45.5 0.4 — 45.9 — 45.9 Storage and Transportation Northeast Storage and Transportation 727.1 (0.8 ) — 726.3 — 726.3 COLT 670.5 (2.2 ) — 668.3 623.4 44.9 Marketing, Supply and Logistics West Coast 89.1 (3.2 ) — 85.9 85.9 — Supply and Logistics 269.5 (3.3 ) — 266.2 99.0 167.2 Storage and Terminals 104.7 (0.5 ) — 104.2 53.7 50.5 US Salt 16.1 (1.3 ) 2.2 12.6 — 12.6 Trucking 178.4 (0.5 ) — 177.9 148.4 29.5 Watkins Glen 94.6 (0.3 ) 28.1 66.2 66.2 — Total Crestwood Midstream $ 2,295.1 $ (11.7 ) $ 48.8 $ 2,234.6 $ 1,149.1 $ 1,085.5 Barnett (Gathering and Processing) 257.2 — — 257.2 257.2 — Total Crestwood Equity $ 2,552.3 $ (11.7 ) $ 48.8 $ 2,491.8 $ 1,406.3 $ 1,085.5 (1) Included in these amounts are approximately $515.4 million and $470.6 million of goodwill impairments recorded at Crestwood Equity and Crestwood Midstream, respectively, during the three months ended December 31, 2015, which primarily resulted from the finalization of the preliminary goodwill impairments recorded on these reporting units during the three months ended September 30, 2015.

Acquisitions (Tables)

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2015
Business Acquisition, Pro Forma Information	The following table presents unaudited pro forma consolidated revenues, net income and net income per limited partner unit as if the reverse mergers and the Arrow Acquisition had been included in our consolidated results for the entire year ended December 31, 2013 ( in millions, except per unit information CEQP CMLP Revenues $ 3,449.3 $ 3,423.8 Net income (loss) $ 3.9 $ (5.0 ) Net income per limited partner unit: Basic $ 0.40 Diluted $ 0.40
Inergy Midstream
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table summarizes the final valuation of the assets acquired and liabilities assumed at the merger date ( in millions CEQP CMLP Current assets $ 224.5 $ 49.1 Property, plant and equipment 2,088.1 1,677.8 Intangible assets 337.5 196.0 Other assets 12.7 2.9 Total identifiable assets acquired 2,662.8 1,925.8 Current liabilities 207.6 30.9 Long-term debt 1,079.3 745.0 Other long-term liabilities 146.6 5.3 Total liabilities assumed 1,433.5 781.2 Net identifiable assets acquired 1,229.3 1,144.6 Goodwill 2,134.8 1,532.7 Net assets acquired $ 3,364.1 $ 2,677.3
Arrow Midstream Holdings, LLC
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table summarizes the final valuation of the assets acquired and liabilities assumed at the acquisition date ( in millions Current assets $ 192.7 Property, plant and equipment 400.5 Intangible assets 323.4 Other assets 19.5 Total identifiable assets acquired 936.1 Current liabilities 215.8 Assets retirement obligations 1.2 Other long-term liabilities 3.7 Total liabilities assumed 220.7 Net identifiable assets acquired 715.4 Goodwill 45.9 Net assets acquired $ 761.3

Certain Balance Sheet Informa32

Certain Balance Sheet Information (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Property, Plant And Equipment		Property, plant and equipment of the following at December 31, 2015 and 2014 ( in millions CEQP CMLP December 31, December 31, 2015 2014 2015 2014 Gathering systems and pipelines $ 1,070.4 $ 1,410.9 $ 1,213.2 $ 1,279.5 Facilities and equipment 1,505.9 1,648.3 1,691.0 1,653.8 Buildings, land, rights-of-way, storage contracts and easements 833.4 841.5 837.1 840.0 Vehicles 46.3 45.2 44.6 43.5 Construction in process 114.5 156.5 114.5 156.5 Base gas 37.3 37.5 37.3 37.5 Salt deposits 120.5 120.5 120.5 120.5 Office furniture and fixtures 19.4 13.5 19.5 13.3 3,747.7 4,273.9 4,077.7 4,144.6 Less: accumulated depreciation and depletion 436.9 380.1 552.0 398.6 Total property, plant and equipment, net $ 3,310.8 $ 3,893.8 $ 3,525.7 $ 3,746.0
Intangible Assets		Intangible assets consisted of the following at December 31, 2015 and 2014 ( in millions CEQP CMLP December 31, December 31, 2015 2014 2015 2014 Customer accounts $ 583.7 $ 583.7 $ 583.7 $ 583.7 Covenants not to compete 6.6 9.6 5.6 8.6 Gas gathering, compression and processing contracts 325.2 730.2 325.2 431.4 Acquired storage contracts 29.0 29.0 29.0 29.0 Trademarks 31.3 32.2 15.8 16.7 Deferred financing costs 63.3 57.2 63.3 54.3 1,039.1 1,441.9 1,022.6 1,123.7 Less: accumulated amortization 229.0 210.6 220.3 154.1 Total intangible assets, net $ 810.1 $ 1,231.3 $ 802.3 $ 969.6
Schedule of Intangible Assets, Future Amortization Expense		Estimated amortization of our intangible assets for the next five years is as follows ( in millions Year Ending December 31, CEQP CMLP 2016 $ 82.9 $ 79.6 2017 69.8 66.7 2018 57.4 55.9 2019 53.8 53.8 2020 52.6 52.6
Schedule of Accrued Liabilities	Accrued expenses and other liabilities consisted of the following at March 31, 2016 and December 31, 2015 ( in millions CEQP CMLP March 31, December 31, March 31, December 31, 2016 2015 2016 2015 Accrued expenses $ 30.7 $ 46.4 $ 29.0 $ 44.1 Accrued property taxes 5.4 4.8 5.4 4.8 Accrued product purchases payable 1.4 1.5 1.4 1.5 Tax payable 1.3 0.5 0.8 0.5 Interest payable 35.6 26.2 35.6 26.2 Accrued additions to property, plant and equipment 5.3 10.4 5.3 10.4 Capital leases 1.4 1.6 1.4 1.6 Deferred revenue 15.7 14.2 15.7 14.2 Total accrued expenses and other liabilities $ 96.8 $ 105.6 $ 94.6 $ 103.3	Accrued expenses and other liabilities consisted of the following at December 31, 2015 and 2014 ( in millions CEQP CMLP December 31, December 31, 2015 2014 2015 2014 Accrued expenses $ 46.4 $ 52.5 $ 44.1 $ 50.0 Accrued property taxes 4.8 2.2 4.8 2.2 Accrued product purchases payable 1.5 0.7 1.5 0.7 Tax payable 0.5 1.6 0.5 1.2 Interest payable 26.2 23.5 26.2 21.9 Accrued additions to property, plant and equipment 10.4 20.0 10.4 20.0 Commitments and contingent liabilities ( Note 15 — 40.0 — 40.0 Capital leases 1.6 1.9 1.6 1.9 Deferred revenue 14.2 12.2 14.2 12.2 Total accrued expenses and other liabilities $ 105.6 $ 154.6 $ 103.3 $ 150.1

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2015 and 2014 ( in millions December 31, 2015 2014 Net asset retirement obligation at January 1 $ 23.8 $ 15.1 Liabilities incurred 1.1 4.6 Acquisitions — 1.2 Accretion expense 1.5 1.1 Changes in estimate — 1.8 Net asset retirement obligation at December 31 $ 26.4 $ 23.8

Investments in Unconsolidated34

Investments in Unconsolidated Affiliates (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Our net investments in and earnings from our unconsolidated affiliates are as follows ( in millions, unless otherwise stated Ownership Investment Earnings from Unconsolidated March 31, March 31, December 31, Three Months Ended March 31, 2016 2016 2015 2016 2015 Jackalope Gas Gathering Services, L.L.C. (1) 50.00 % (4) $ 202.4 $ 202.4 $ 5.1 $ 2.5 Tres Palacios Holdings LLC (2) 50.01 % 43.1 36.8 0.8 0.9 Powder River Basin Industrial Complex, LLC (3) 50.01 % 15.1 15.1 0.6 — Total $ 260.6 $ 254.3 $ 6.5 $ 3.4 (1) As of March 31, 2016, our equity in the underlying net assets of Jackalope Gas Gathering Services, L.L.C. (Jackalope) exceeded our investment balance by approximately $0.9 million. We amortize this amount over 20 years, which represents the life of Jackalope’s gathering agreement with Chesapeake Energy Corporation (Chesapeake), and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of less than $0.1 million and $0.8 million for the three months ended March 31, 2016 and 2015. Our Jackalope investment is included in our gathering and processing segment. (2) As of March 31, 2016, our equity in the underlying net assets of Tres Palacios Holdings LLC (Tres Holdings) exceeded our investment balance by approximately $28.8 million. We amortize this amount over the life of the Tres Palacios Gas Storage LLC (Tres Palacios) sublease agreement, and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of $0.3 millionduring each of the three months ended March 31, 2016 and 2015. Our Tres Holdings investment is included in our storage and transportation segment. (3) As of March 31, 2016, our equity in the underlying net assets of PRBIC exceeded our investment balance by approximately $23.0 million. We amortize this amount over the life of PRBIC’s property, plant and equipment and its agreement with Chesapeake, and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of approximately $0.4 million for the three months ended March 31, 2016. Our PRBIC investment is included in our storage and transportation segment. (4) Excludes non-controlling interests related to our investment in Jackalope. See Note 9 for a further discussion of our non-controlling interest related to our investment in Jackalope.	Net Investments and Earnings (Loss) Ownership Investment Earnings (Loss) from December 31, 2015 December 31, Year Ended December 31, 2015 2014 2015 2014 2013 Jackalope Gas Gathering Services, L.L.C. (1) 50.00 % (4) $ 202.4 $ 232.9 $ (43.4 ) (5) $ 0.5 $ 0.1 Tres Palacios Holdings LLC (2) 50.01 % 36.8 36.0 2.5 0.2 — Powder River Basin Industrial Complex, LLC (3) 50.01 % 15.1 26.2 (19.9 ) (5) (1.4 ) (0.2 ) Total $ 254.3 $ 295.1 $ (60.8 ) $ (0.7 ) $ (0.1 ) (1) As of December 31, 2015, our equity in the underlying net assets of Jackalope exceeded our investment balance by approximately $0.9 million. We amortize this amount over 20 years, which represents the life of Jackalope’s gathering agreement with Chesapeake Energy Corporation (Chesapeake), and we reflect the amortization as a reduction of our earnings from unconsolidated affiliates. We recorded amortization of approximately $3.0 million, $3.1 million and $1.4 million for the years ended December 31, 2015, 2014 and 2013. (2) As of December 31, 2015, our equity in the underlying net assets of Tres Holdings exceeded our investment balance by approximately $29.1 million. We amortize and generally assess the recoverability of this amount over the life of the Tres Palacios Gas Storage LLC (Tres Palacios) sublease agreement, and we reflect the amortization as an increase in our earnings from unconsolidated affiliates. We recorded amortization of approximately $1.3 million and $0.1 million for the years ended December 31, 2015 and 2014. (3) As of December 31, 2015, our equity in the underlying net assets of PRBIC exceeded our investment balance by approximately $23.4 million. We amortize this amount over the life of PRBIC’s property, plant and equipment and its agreement with Chesapeake. During the three months ended June 30, 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. (4) Excludes non-controlling interests related to our investment in Jackalope. See Note 12 for a further discussion of our non-controlling interest related to our investment in Jackalope. (5) During the year ended December 31, 2015, we recorded impairments of our Jackalope and PRBIC equity investments of approximately $51.4 million and $23.4 million. For a further discussion of these impairments, see Note 2.

Risk Management (Tables)

Risk Management (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Notional Amounts And Terms Of Company's Derivative Financial Instruments	The notional amounts and terms of our derivative financial instruments include the following at March 31, 2016 and December 31, 2015 ( in millions March 31, 2016 December 31, 2015 Fixed Price Payor Fixed Price Receiver Fixed Price Payor Fixed Price Receiver Propane, crude and heating oil ( barrels 10.6 11.9 9.1 10.9	The notional amounts and terms of our derivative financial instruments include the following at December 31, 2015 and 2014( in millions December 31, 2015 December 31, 2014 Fixed Price Payor Fixed Price Receiver Fixed Price Payor Fixed Price Receiver Propane, crude and heating oil ( barrels 9.1 10.9 6.8 8.4 Natural gas ( MMBTU’s — — 0.2 0.1

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	We estimate the fair value of our senior notes primarily based on quoted market prices for the same or similar issuances (representing a Level 2 fair value measurement). The following table reflects the carrying value and fair value of our CMLP senior notes ( in millions March 31, 2016 December 31, 2015 Carrying Amount Fair Value Carrying Fair Value Crestwood Midstream 2020 Senior Notes $ 503.2 $ 399.8 $ 503.3 $ 382.3 Crestwood Midstream 2022 Senior Notes $ 600.0 $ 446.0 $ 600.0 $ 437.4 Crestwood Midstream 2023 Senior Notes $ 700.0 $ 519.8 $ 700.0 $ 491.8	The following table reflects the carrying value and fair value of the senior notes ( in millions December 31, 2015 December 31, 2014 Carrying Fair Value Carrying Fair CEQP Senior Notes $ — $ — $ 11.4 $ 11.6 Crestwood Midstream 2019 Senior Notes $ — $ — $ 351.0 $ 360.5 Crestwood Midstream 2020 Senior Notes $ 503.3 $ 382.3 $ 504.0 $ 481.6 Crestwood Midstream 2022 Senior Notes $ 600.0 $ 437.4 $ 600.0 $ 568.5 Crestwood Midstream 2023 Senior Notes $ 700.0 $ 491.8 $ — $ —
Assets And Liabilities Measured At Fair Value On Recurring Basis	The following tables set forth by level within the fair value hierarchy, our financial instruments that were accounted for at fair value on a recurring basis at March 31, 2016 and December 31, 2015 ( in millions March 31, 2016 Fair Value of Derivatives Level 1 Level 2 Level 3 Gross Fair Contract (1) Collateral/Margin Received or Paid Recorded in Assets Assets from price risk management $ 0.4 $ 32.2 $ — $ 32.6 $ (19.7 ) $ 1.5 $ 14.4 Suburban Propane Partners, L.P. units (2) 4.2 — — 4.2 — — 4.2 Total assets at fair value $ 4.6 $ 32.2 $ — $ 36.8 $ (19.7 ) $ 1.5 $ 18.6 Liabilities Liabilities from price risk management $ 0.2 $ 26.6 $ — $ 26.8 $ (19.7 ) $ 0.2 $ 7.3 Total liabilities at fair value $ 0.2 $ 26.6 $ — $ 26.8 $ (19.7 ) $ 0.2 $ 7.3 December 31, 2015 Fair Value of Derivatives Level 1 Level 2 Level 3 Gross Fair Contract (1) Collateral/Margin Received Recorded in Assets Assets from price risk management $ 0.5 $ 57.8 $ — $ 58.3 $ (13.7 ) $ (12.0 ) $ 32.6 Suburban Propane Partners, L.P. units (2) 3.4 — — 3.4 — — 3.4 Total assets at fair value $ 3.9 $ 57.8 $ — $ 61.7 $ (13.7 ) $ (12.0 ) $ 36.0 Liabilities Liabilities from price risk management $ 0.2 $ 41.3 $ — $ 41.5 $ (13.7 ) $ (20.4 ) $ 7.4 Total liabilities at fair value $ 0.2 $ 41.3 $ — $ 41.5 $ (13.7 ) $ (20.4 ) $ 7.4 (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.	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, 2015 and 2014 ( in millions December 31, 2015 Fair Value of Derivatives Level 1 Level 2 Level 3 Gross Contract (1) Collateral/Margin Recorded in Assets Assets from price risk management $ 0.5 $ 57.8 $ — $ 58.3 $ (13.7 ) $ (12.0 ) $ 32.6 Suburban Propane Partners, L.P. units (2) 3.4 — — 3.4 — — 3.4 Total assets at fair value $ 3.9 $ 57.8 $ — $ 61.7 $ (13.7 ) $ (12.0 ) $ 36.0 Liabilities Liabilities from price risk management $ 0.2 $ 41.3 $ — $ 41.5 $ (13.7 ) $ (20.4 ) $ 7.4 Total liabilities at fair value $ 0.2 $ 41.3 $ — $ 41.5 $ (13.7 ) $ (20.4 ) $ 7.4 December 31, 2014 Fair Value of Derivatives Level 1 Level 2 Level 3 Gross Contract (1) Collateral/Margin Recorded in Assets Assets from price risk management $ 0.5 $ 146.7 $ — $ 147.2 $ (28.8 ) $ (38.6 ) $ 79.8 Suburban Propane Partners, L.P. units (2) 6.1 — — 6.1 — — 6.1 Total assets at fair value $ 6.6 $ 146.7 $ — $ 153.3 $ (28.8 ) $ (38.6 ) $ 85.9 Liabilities Liabilities from price risk management $ 1.6 $ 99.2 $ — $ 100.8 $ (28.8 ) $ (46.6 ) $ 25.4 Interest rate swaps (3) — 1.6 — 1.6 — — 1.6 Total liabilities at fair value $ 1.6 $ 100.8 $ — $ 102.4 $ (28.8 ) $ (46.6 ) $ 27.0 (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 the Crestwood Equity Partners LP consolidated balance sheet. (3) Our interest rate swaps are only reflected in the consolidated results of Crestwood Equity. See Note 9 for a further discussion of our interest rate swaps.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Debt Disclosure [Abstract]
Components Of Long-Term Debt	Long-term debt consisted of the following at March 31, 2016 and December 31, 2015 ( in millions March 31, 2016 December 31, 2015 Credit Facility $ 762.8 $ 735.0 2020 Senior Notes 500.0 500.0 Fair value adjustment of 2020 Senior Notes 3.2 3.3 2022 Senior Notes 600.0 600.0 2023 Senior Notes 700.0 700.0 Other 4.9 5.3 Less: deferred financing costs, net 39.2 40.9 Total Crestwood Midstream debt 2,531.7 2,502.7 Other — 0.2 Total Crestwood Equity debt 2,531.7 2,502.9 Less: current portion 0.9 1.1 Total long-term debt, less current portion $ 2,530.8 $ 2,501.8	Long-term debt consisted of the following at December 31, 2015 and 2014, ( in millions December 31, December 31, CMLP Credit Facility $ 735.0 $ 555.0 Crestwood Midstream 2019 Senior Notes — 350.0 Premium on Crestwood Midstream 2019 Senior Notes — 1.0 Crestwood Midstream 2020 Senior Notes 500.0 500.0 Fair value adjustment of Crestwood Midstream 2020 Senior Notes 3.3 4.0 Crestwood Midstream 2022 Senior Notes 600.0 600.0 Crestwood Midstream 2023 Senior Notes 700.0 — Other 5.3 5.3 Total Crestwood Midstream debt 2,543.6 2,015.3 CEQP Credit Facility — 369.0 CEQP Senior Notes — 11.4 Other 0.2 0.8 Total Crestwood Equity debt 2,543.8 2,396.5 Less: current portion 1.1 3.7 Total long-term debt, less current portion $ 2,542.7 $ 2,392.8
Schedule of Maturities of Long-term Debt		The aggregate maturities of principal amounts on our outstanding long-term debt and other notes payable as of December 31, 2015 for the next five years and in total thereafter are as follows ( in millions CEQP CMLP 2016 $ 1.1 $ 0.9 2017 1.0 1.0 2018 1.0 1.0 2019 1.1 1.1 2020 1,238.6 1,238.6 Thereafter 1,301.0 1,301.0 Total debt $ 2,543.8 $ 2,543.6

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	The provision (benefit) for income taxes for the years ended December 31, 2015, 2014, and 2013 consisted of the following (in millions) CEQP CMLP Year Ended December 31, Year Ended December 31, 2015 2014 2013 2015 2014 2013 Current: Federal $ 1.6 $ 5.0 $ 2.5 $ — $ — $ — State 0.6 1.3 1.3 0.3 0.2 0.7 Total current 2.2 6.3 3.8 0.3 0.2 0.7 Deferred: Federal (2.9 ) (5.3 ) (2.5 ) — — — State (0.7 ) 0.1 (0.3 ) (0.3 ) 0.7 — Total deferred (3.6 ) (5.2 ) (2.8 ) (0.3 ) 0.7 — Provision (benefit) for income taxes $ (1.4 ) $ 1.1 $ 1.0 $ — $ 0.9 $ 0.7
Schedule of Deferred Tax Assets and Liabilities	Components of our deferred income taxes at December 31, 2015 and 2014 are as follows (in millions). CEQP CMLP December 31, December 31, 2015 2014 2015 2014 Deferred tax asset: Basis difference in stock of company $ 0.5 $ — $ — $ — Total deferred tax asset 0.5 — — — Deferred tax liability: Basis difference in stock of acquired company (8.9 ) (12.0 ) (0.4 ) (0.7 ) Total deferred tax liability (8.9 ) (12.0 ) (0.4 ) (0.7 ) Net deferred tax liability $ (8.4 ) $ (12.0 ) $ (0.4 ) $ (0.7 )

Partners' Capital (Tables)

Partners' Capital (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Schedule of Limited Partners' Capital Account by Class		The table below presents limited partner unit issuances by Legacy Crestwood, Inergy Midstream and Crestwood Midstream. Issuer Issuance Date Units Per Unit Gross Price Per Unit Net Price (1) Net Proceeds (in millions) Legacy Crestwood March 22, 2013 5,175,000 (2) 23.90 23.00 118.5 Inergy Midstream September 13, 2013 11,773,191 (3) 22.50 21.69 255.2 Crestwood Midstream October 23, 2013 16,100,000 (4) N/A 21.19 340.3 (1) Price is net of underwriting discounts. (2) Includes 675,000 units that were issued in April 2013. (3) Includes 773,191 units that were issued on October 7, 2013. (4) Includes 2,100,000 units that were issued on October 30, 2013. The components of net income (loss) attributable to non-controlling partners for the years ended December 31, 2015, 2014 and 2013 are as follows (in millions) Year Ended December 31, 2015 2014 2013 Crestwood Niobrara preferred interests $ 23.1 $ 16.8 $ 4.9 CMLP net income attributable to non-controlling partners 23.1 16.8 4.9 Crestwood Midstream limited partner interests (683.0 ) (100.8 ) (62.2 ) Crestwood Midstream Class A preferred units 23.1 17.2 — CEQP net income (loss) attributable to non-controlling partners $ (636.8 ) $ (66.8 ) $ (57.3 )
Schedule of Distributions Made to Members or Limited Partners, by Distribution	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 three months ended March 31, 2015. Record Date Payment Date Per Cash (in millions) February 6, 2015 February 13, 2015 $ 0.41 $ 74.3	A summary of CEQP’s limited partner quarterly cash distributions for the years ended December 31, 2015, 2014 and 2013 is presented below: Record Date Payment Date Per Unit Rate Cash Distributions (in millions) 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 2014 February 7, 2014 February 14, 2014 $ 1.375 $ 25.6 May 8, 2014 May 15, 2014 $ 1.375 25.7 August 7, 2014 August 14, 2014 $ 1.375 25.6 November 7, 2014 November 14, 2014 $ 1.375 25.6 $ 102.5 2013 August 7, 2013 August 14, 2013 $ 1.30 $ 22.3 November 7, 2013 November 14, 2013 $ 1.35 25.0 $ 47.3 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 years ended December 31, 2015, 2014 and 2013. 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 2014 February 7, 2014 February 14, 2014 $ 0.41 $ 74.1 May 8, 2014 May 15, 2014 $ 0.41 74.2 August 7, 2014 August 14, 2014 $ 0.41 74.1 November 7, 2014 November 14, 2014 $ 0.41 74.1 $ 296.5 2013 January 31, 2013 February 12, 2013 $ 0.510 $ 21.0 April 30, 2013 May 10, 2013 $ 0.510 27.4 August 1, 2013 August 9, 2013 $ 0.510 27.4 August 7, 2013(1) August 14, 2013 $ 0.400 34.3 November 7, 2013 (1) November 14, 2013 $ 0.405 69.5 $ 179.6 (1) Represents distributions associated with Inergy Midstream limited partner units.
Components of Net Income (Loss) Attributable to Non-Controlling Partners	The components of net income (loss) attributable to non-controlling partners for the three months ended March 31, 2016 and 2015, are as follows (in millions) Three Months Ended 2016 2015 Crestwood Niobrara preferred interests $ 5.9 $ 5.6 CMLP net income attributable to non-controlling partners 5.9 5.6 Crestwood Midstream limited partner interests — (5.0 ) Crestwood Midstream Class A preferred units — 9.2 CEQP net income attributable to non-controlling partners $ 5.9 $ 9.8
Crestwood Equity Partners LP
Schedule of Distributions Made to Members or Limited Partners, by Distribution	A summary of CEQP’s limited partner quarterly cash distributions for the three months ended March 31, 2016 and 2015 is presented below: Record Date Payment Date Per Cash (in millions) 2016 February 5, 2016 February 12, 2016 $ 1.375 $ 95.6 2015 February 6, 2015 February 13, 2015 $ 1.375 $ 25.8

Equity Plans (Tables)

Equity Plans (Tables)	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Disclosure of Share-based Compensation Arrangements by Share-based Payment Award	The restricted and phantom units in the table below have been recast to reflect the reverse split. Units Weighted-Average Grant Unvested—January 1, 2014 49,354 $ 139.60 Vested—restricted units (44,993 ) $ 139.70 Granted—restricted units 137,746 $ 132.30 Forfeited (10,519 ) $ 137.30 Unvested—December 31, 2014 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 (1) We implemented a company-wide initiative to reduce operating costs in 2015 and beyond, which included a reduction in work force. As a result, 7,263 restricted units were forfeited during the year ended December 31, 2015. The following table summarizes information regarding restricted and phantom unit activity during the years ended December 31, 2015 and 2014: Units Weighted-Average Grant Unvested—January 1, 2014 250,557 $ 22.13 Vested—restricted units (208,361 ) $ 22.15 Granted—restricted units 871,078 $ 23.25 Forfeited (78,478 ) $ 23.33 Unvested—December 31, 2014 834,796 $ 23.18 Vested—restricted units (457,458 ) $ 22.91 Vested—phantom units (21,578 ) $ 16.05 Granted—restricted units 535,858 $ 15.89 Granted—phantom units 171,648 $ 15.76 Modification—restricted units (823,277 ) $ 20.06 Modification—phantom units (150,070 ) $ 18.93 Forfeited (1) (89,919 ) $ 16.05 Unvested—December 31, 2015 — $ — (1) We implemented a company-wide initiative to reduce operating costs in 2015 and beyond, which included a reduction in work force. As a result, 39,172 restricted units were forfeited during the year ended December 31, 2015.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2016 $ 19.1 2017 16.6 2018 15.3 2019 14.1 2020 9.2 Thereafter 23.8 Total minimum lease payments $ 98.1

Related Party Transactions (Tab

Related Party Transactions (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	The following table shows revenues, costs of product/services sold, general and administrative expenses and reimbursements of expenses from our affiliates for the three months ended March 31, 2016 and 2015 ( in millions Three Months Ended 2016 2015 Gathering and processing revenues at CEQP and CMLP $ 0.7 $ 1.0 Gathering and processing costs of product/services sold at CEQP and CMLP (1) $ 4.3 $ 8.3 Operations and maintenance expenses charged at CEQP and CMLP $ 0.7 $ 0.9 General and administrative expenses charged by CEQP to CMLP, net (2) $ 3.7 $ 17.4 General and administrative expenses charged by CEQP to Crestwood Holdings, net (3) $ 0.1 $ 0.1 (1) Represents natural gas purchases from Sabine Oil and Gas Corporation. (2) Includes $4.5 million and $2.2 million of net unit-based compensation charges allocated from CEQP to CMLP for three months ended March 31, 2016 and 2015. In addition, prior to the completion of the Simplification Merger, CEQP allocated general and administrative costs to CMLP. In conjunction with the Simplification Merger, CMLP shares common management, general and administrative and overhead costs with CEQP. During the three months ended March 31, 2016, CMLP allocated $0.8 million of general and administrative costs to CEQP. (3) Includes less than $0.1 million unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the three months ended 2016.	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, 2015, 2014 and 2013 ( in millions Year Ended December 31, 2015 2014 2013 Gathering and processing revenues at CEQP and CMLP $ 3.9 $ 3.0 $ 74.9 Gathering and processing costs of product/services sold at CEQP and CMLP (1) $ 28.9 $ 42.2 $ 32.5 Operations and maintenance expenses charged at CEQP and CMLP $ 2.8 $ 0.2 $ — General and administrative expenses charged by CEQP to CMLP, net (2) $ 49.5 $ 63.6 $ 34.7 General and administrative expenses charged by CEQP to Crestwood Holdings, net (3) $ 0.4 $ 0.5 $ 25.3 (1) Represents natural gas purchases from Sabine Oil and Gas. (2) Includes $10.0 million, $6.9 million and $4.4 million of net unit-based compensation charges allocated from CEQP to CMLP for the years ended December 31, 2015, 2014 and 2013. (3) Includes $0.1 million unit-based compensation charges allocated from Crestwood Holdings to CMLP during the year ended December 31, 2015.
Schedule of Related Party Receivables and Payables	The following table shows accounts receivable and accounts payable from our affiliates as of March 31, 2016 and December 31, 2015 ( in millions CEQP CMLP March 31, 2016 December 31, 2015 March 31, 2016 December 31, 2015 Accounts receivable $ 1.1 $ 1.7 $ 1.1 $ 1.7 Accounts payable $ 3.8 $ 4.0 $ 1.3 $ 1.5	The following table shows accounts receivable and accounts payable from our affiliates as of December 31, 2015 and 2014 ( in millions CEQP CMLP December 31, December 31, 2015 2014 2015 2014 Accounts receivable $ 1.7 $ 0.6 $ 1.7 $ 0.3 Accounts payable $ 4.0 $ 5.6 $ 1.5 $ 3.1

Segments (Tables)

Segments (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Reconciliation of Net Income (Loss) to Earnings Before Interest, Taxes, Depreciation and Amortization	Below is a reconciliation of CMLP’s net income to EBITDA ( in millions Three Months Ended 2016 2015 Net income (loss) $ (95.3 ) $ 29.1 Add: Interest and debt expense, net 36.1 29.9 Provision (benefit) for income taxes (0.2 ) 0.4 Depreciation, amortization and accretion 64.9 68.8 EBITDA $ 5.5 $ 128.2
Reportable Segments	Three Months Ended March 31, 2016 Gathering and Storage and Marketing, Supply and Corporate Total Revenues $ 238.9 $ 59.4 $ 237.7 $ — $ 536.0 Intersegment revenues 20.5 0.4 (20.9 ) — — Costs of product/services sold 179.8 2.9 180.7 — 363.4 Operations and maintenance expense 17.8 7.1 16.8 — 41.7 General and administrative expense — — — 22.2 22.2 Goodwill impairment (8.6 ) (13.7 ) (87.4 ) — (109.7 ) Earnings from unconsolidated affiliates, net 5.1 1.4 — — 6.5 EBITDA $ 58.3 $ 37.5 $ (68.1 ) $ (22.2 ) $ 5.5 Goodwill $ 45.9 $ 757.5 $ 172.4 $ — $ 975.8 Total assets $ 2,534.1 $ 2,185.0 $ 924.4 $ 123.9 $ 5,767.4 Purchases of property, plant and equipment $ 44.3 $ 3.3 $ 7.1 $ 0.9 $ 55.6 Three Months Ended March 31, 2015 Gathering and Storage and Marketing, Supply and Corporate Total Revenues $ 350.3 $ 67.6 $ 313.6 $ — $ 731.5 Intersegment revenues 10.1 — (10.1 ) — — Costs of product/services sold 266.7 5.3 257.7 — 529.7 Operations and maintenance expense 24.1 6.4 20.1 — 50.6 General and administrative expense — — — 25.6 25.6 Loss on long-lived assets (0.3 ) (0.5 ) — — (0.8 ) Earnings from unconsolidated affiliates, net 2.5 0.9 — — 3.4 EBITDA $ 71.8 $ 56.3 $ 25.7 $ (25.6 ) $ 128.2 Purchases of property, plant and equipment $ 36.2 $ 4.1 $ 6.9 $ 0.2 $ 47.4	Below is a reconciliation of CEQP’s net income to EBITDA ( in millions Year Ended December 31, 2015 2014 2013 Net loss $ (2,303.7 ) $ (10.4 ) $ (50.6 ) Add: Interest and debt expense, net 140.1 127.1 77.9 Loss on modification/extinguishment of debt 20.0 — — Provision (benefit) for income taxes (1.4 ) 1.1 1.0 Depreciation, amortization and accretion 300.1 285.3 167.9 EBITDA $ (1,844.9 ) $ 403.1 $ 196.2 The following tables summarize CEQP’s reportable segment data for the years ended December 31, 2015, 2014 and 2013 ( in millions Year Ended December 31, 2015 Gathering and Storage and Marketing, 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, net (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 ) Goodwill $ 54.5 $ 771.2 $ 259.8 $ — $ 1,085.5 Total assets $ 2,325.2 $ 2,217.4 $ 1,083.7 $ 177.4 $ 5,803.7 Purchases of property, plant and equipment $ 132.7 $ 26.4 $ 22.8 $ 0.8 $ 182.7 Year Ended December 31, 2014 Gathering and Storage and Marketing, Corporate Total Revenues $ 2,166.8 $ 264.6 $ 1,499.9 $ — $ 3,931.3 Intersegment revenues 50.0 — (50.0 ) — — Costs of product/services sold 1,859.9 33.3 1,272.1 — 3,165.3 Operations and maintenance expense 102.8 28.8 71.7 — 203.3 General and administrative expense — — — 100.2 100.2 Gain (loss) on long-lived assets (32.7 ) 33.8 (3.0 ) — (1.9 ) Goodwill impairment (18.5 ) — (30.3 ) — (48.8 ) Loss on contingent consideration (8.6 ) — — — (8.6 ) Earnings (loss) from unconsolidated affiliates 0.5 (1.2 ) — — (0.7 ) Other income, net — — — 0.6 0.6 EBITDA $ 194.8 $ 235.1 $ 72.8 $ (99.6 ) $ 403.1 Goodwill $ 384.2 $ 1,394.6 $ 713.0 $ — $ 2,491.8 Total assets $ 3,593.6 $ 2,423.3 $ 2,240.6 $ 203.9 $ 8,461.4 Purchases of property, plant and equipment $ 327.9 $ 37.0 $ 50.9 $ 8.2 $ 424.0 Year Ended December 31, 2013 Gathering and Storage and Marketing, Corporate Total Revenues $ 510.0 $ 130.9 $ 785.8 $ — $ 1,426.7 Costs of product/services sold 267.5 19.7 715.1 — 1,002.3 Operations and maintenance expense 58.7 14.2 31.7 — 104.6 General and administrative expense — — — 93.5 93.5 Gain (loss) on long-lived assets 5.4 — (0.1 ) — 5.3 Goodwill impairment (4.1 ) — — — (4.1 ) Gain on contingent consideration (31.4 ) — — — (31.4 ) Earnings (loss) from unconsolidated affiliates 0.1 (0.2 ) — — (0.1 ) Other income, net — — — 0.2 0.2 EBITDA $ 153.8 $ 96.8 $ 38.9 $ (93.3 ) $ 196.2 Purchases of property, plant and equipment $ 290.7 $ 43.4 $ 11.9 $ 1.0 $ 347.0 Below is a reconciliation of CMLP’s net income to EBITDA ( in millions Year Ended December 31, 2015 2014 2013 Net income (loss) $ (1,410.6 ) $ 14.7 $ (12.4 ) Add: Interest and debt expense, net 130.5 111.4 71.7 Loss on modification/extinguishment of debt 18.9 — — Provision for income taxes — 0.9 0.7 Depreciation, amortization and accretion 278.5 255.4 139.4 EBITDA $ (982.7 ) $ 382.4 $ 199.4 The following tables summarize CMLP’s reportable segment data for the years ended December 31, 2015, 2014 and 2013 ( in millions Year Ended December 31, 2015 Gathering and Storage and Marketing, 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 ) Goodwill $ 54.5 $ 771.2 $ 259.8 $ — $ 1,085.5 Total assets $ 2,541.6 $ 2,216.7 $ 1,083.7 $ 162.5 $ 6,004.5 Purchases of property, plant and equipment $ 132.7 $ 26.4 $ 22.8 $ 0.8 $ 182.7 Year Ended December 31, 2014 Gathering and Storage and Marketing, Corporate Total Revenues $ 2,166.8 $ 250.8 $ 1,499.9 $ — $ 3,917.5 Intersegment revenues 50.0 — (50.0 ) — — Costs of product/services sold 1,859.9 22.8 1,272.1 — 3,154.8 Operations and maintenance expense 102.8 22.1 70.5 — 195.4 General and administrative expense — — — 91.7 91.7 Gain (loss) on long-lived assets, net (32.7 ) 0.6 (3.0 ) — (35.1 ) Goodwill impairment (18.5 ) — (30.3 ) — (48.8 ) Loss on contingent consideration (8.6 ) — — — (8.6 ) Earnings (loss) from unconsolidated affiliates, net 0.5 (1.2 ) — — (0.7 ) EBITDA $ 194.8 $ 205.3 $ 74.0 $ (91.7 ) $ 382.4 Goodwill $ 127.0 $ 1,394.6 $ 713.0 $ — $ 2,234.6 Total assets $ 2,941.6 $ 2,423.3 $ 2,240.6 $ 179.7 $ 7,785.2 Purchases of property, plant and equipment $ 327.9 $ 36.4 $ 50.9 $ 6.5 $ 421.7 Year Ended December 31, 2013 Gathering and Storage and Marketing, Corporate Total Revenues $ 510.0 $ 116.8 $ 785.8 $ — $ 1,412.6 Costs of product/services sold 267.5 12.8 715.1 — 995.4 Operations and maintenance expense 58.7 12.4 32.3 — 103.4 General and administrative expense — — — 84.1 84.1 Gain on long-lived assets 5.4 — (0.1 ) — 5.3 Goodwill impairment (4.1 ) — — — (4.1 ) Loss on contingent consideration (31.4 ) — — — (31.4 ) Earnings (loss) from unconsolidated affiliates, net 0.1 (0.2 ) — — (0.1 ) EBITDA $ 153.8 $ 91.4 $ 38.3 $ (84.1 ) $ 199.4 Purchases of property, plant and equipment $ 290.7 $ 35.7 $ 11.9 $ 1.0 $ 339.3
Crestwood Equity Partners LP
Reconciliation of Net Income (Loss) to Earnings Before Interest, Taxes, Depreciation and Amortization	Below is a reconciliation of CEQP’s net income to EBITDA ( in millions Three Months Ended March 31, 2016 2015 Net income (loss) $ (93.7 ) $ 18.1 Add: Interest and debt expense, net 36.1 33.6 Provision for income taxes — 0.4 Depreciation, amortization and accretion 62.3 74.2 EBITDA $ 4.7 $ 126.3
Reportable Segments	Three Months Ended March 31, 2016 Gathering and Storage and Marketing, Supply and Corporate Total Revenues $ 238.9 $ 59.4 $ 237.7 $ — $ 536.0 Intersegment revenues 20.5 0.4 (20.9 ) — — Costs of product/services sold 179.8 2.9 180.7 — 363.4 Operations and maintenance expense 17.8 7.2 16.8 — 41.8 General and administrative expense — — — 23.0 23.0 Goodwill impairment (8.6 ) (13.7 ) (87.4 ) — (109.7 ) Earnings from unconsolidated affiliates, net 5.1 1.4 — — 6.5 Other income, net — — — 0.1 0.1 EBITDA $ 58.3 $ 37.4 $ (68.1 ) $ (22.9 ) $ 4.7 Goodwill $ 45.9 $ 757.5 $ 172.4 $ — $ 975.8 Total assets $ 2,321.2 $ 2,185.7 $ 924.4 $ 138.7 $ 5,570.0 Purchases of property, plant and equipment $ 44.3 $ 3.3 $ 7.1 $ 0.9 $ 55.6 Three Months Ended March 31, 2015 Gathering and Processing Storage and Marketing, Supply and Logistics Corporate Total Revenues $ 350.3 $ 67.6 $ 313.6 $ — $ 731.5 Intersegment revenues 10.1 — (10.1 ) — — Costs of product/services sold 266.7 5.3 257.7 — 529.7 Operations and maintenance expense 24.1 6.4 20.1 — 50.6 General and administrative expense — — — 27.5 27.5 Loss on long-lived assets (0.3 ) (0.7 ) — — (1.0 ) Earnings from unconsolidated affiliates, net 2.5 0.9 — — 3.4 Other income, net — — — 0.2 0.2 EBITDA $ 71.8 $ 56.1 $ 25.7 $ (27.3 ) $ 126.3 Purchases of property, plant and equipment $ 36.2 $ 4.1 $ 6.9 $ 0.2 $ 47.4

Condensed Consolidating Finan44

Condensed Consolidating Financial Information (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Text Block [Abstract]
Condensed Balance Sheet	Crestwood Midstream Partners LP Condensed Consolidating Balance Sheet March 31, 2016 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Assets Current assets: Cash $ 0.8 $ — $ — $ — $ 0.8 Accounts receivable — 209.1 0.5 — 209.6 Inventory — 26.6 — — 26.6 Other current assets — 33.3 — — 33.3 Total current assets 0.8 269.0 0.5 — 270.3 Property, plant and equipment, net — 3,514.4 — — 3,514.4 Goodwill and intangible assets, net — 1,719.1 — — 1,719.1 Investment in consolidated affiliates 5,350.2 — — (5,350.2 ) — Investment in unconsolidated affiliates — — 260.6 — 260.6 Other assets — 3.0 — — 3.0 Total assets $ 5,351.0 $ 5,505.5 $ 261.1 $ (5,350.2 ) $ 5,767.4 Liabilities and partners’ capital Current liabilities: Accounts payable $ — $ 116.5 $ — $ — $ 116.5 Other current liabilities 35.8 67.0 — — 102.8 Total current liabilities 35.8 183.5 — — 219.3 Long-term liabilities: Long-term debt, less current portion 2,528.2 2.6 — — 2,530.8 Other long-term liabilities — 44.1 — — 44.1 Deferred income taxes — 0.6 — — 0.6 Partners’ capital 2,787.0 5,274.7 75.5 (5,350.2 ) 2,787.0 Interest of non-controlling partners in subsidiaries — — 185.6 — 185.6 Total partners’ capital 2,787.0 5,274.7 261.1 (5,350.2 ) 2,972.6 Total liabilities and partners’ capital $ 5,351.0 $ 5,505.5 $ 261.1 $ (5,350.2 ) $ 5,767.4 Crestwood Midstream Partners LP Condensed Consolidating Balance Sheet December 31, 2015 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Assets Current assets: Cash $ 0.1 $ — $ — $ — $ 0.1 Accounts receivable — 236.0 0.5 — 236.5 Inventory — 44.5 — — 44.5 Other current assets — 52.5 — — 52.5 Total current assets 0.1 333.0 0.5 — 333.6 Property, plant and equipment, net — 3,525.7 — — 3,525.7 Goodwill and intangible assets, net — 1,846.9 — — 1,846.9 Investment in consolidated affiliates 5,506.8 — — (5,506.8 ) — Investment in unconsolidated affiliates — — 254.3 — 254.3 Other assets — 3.1 — — 3.1 Total assets $ 5,506.9 $ 5,708.7 $ 254.8 $ (5,506.8 ) $ 5,963.6 Liabilities and partners’ capital Current liabilities: Accounts payable $ — $ 141.3 $ 0.1 $ — $ 141.4 Other current liabilities 26.4 85.2 — — 111.6 Total current liabilities 26.4 226.5 0.1 — 253.0 Long-term liabilities: Long-term debt, less current portion 2,498.9 2.9 — — 2,501.8 Other long-term liabilities — 43.3 — — 43.3 Deferred income taxes — 0.4 — — 0.4 Partners’ capital 2,981.6 5,435.6 71.2 (5,506.8 ) 2,981.6 Interest of non-controlling partners in subsidiaries — — 183.5 — 183.5 Total partners’ capital 2,981.6 5,435.6 254.7 (5,506.8 ) 3,165.1 Total liabilities and partners’ capital $ 5,506.9 $ 5,708.7 $ 254.8 $ (5,506.8 ) $ 5,963.6	Crestwood Midstream Partners LP Condensed Consolidating Balance Sheet December 31, 2015 (in millions) Parent Guarantor Subsidiaries Non- Eliminations Consolidated Assets Current assets: Cash $ 0.1 $ — $ — $ — $ 0.1 Accounts receivable — 236.0 0.5 — 236.5 Inventory — 44.5 — — 44.5 Other current assets — 52.5 — — 52.5 Total current assets 0.1 333.0 0.5 — 333.6 Property, plant and equipment, net — 3,525.7 — — 3,525.7 Goodwill and intangible assets, net 40.9 1,846.9 — — 1,887.8 Investment in consolidated affiliates 5,506.8 — — (5,506.8 ) — Investment in unconsolidated affiliates — — 254.3 — 254.3 Other assets — 3.1 — — 3.1 Total assets $ 5,547.8 $ 5,708.7 $ 254.8 $ (5,506.8 ) $ 6,004.5 Liabilities and partners’ capital Current liabilities: Accounts payable — 141.3 0.1 — 141.4 Other current liabilities 26.4 85.2 — — 111.6 Total current liabilities 26.4 226.5 0.1 — 253.0 Long-term liabilities: Long-term debt, less current portion 2,539.8 2.9 — — 2,542.7 Other long-term liabilities — 43.3 — — 43.3 Deferred income taxes — 0.4 — — 0.4 Partners’ capital 2,981.6 5,435.6 71.2 (5,506.8 ) 2,981.6 Interest of non-controlling partners in subsidiaries — — 183.5 — 183.5 Total partners’ capital 2,981.6 5,435.6 254.7 (5,506.8 ) 3,165.1 Total liabilities and partners’ capital $ 5,547.8 $ 5,708.7 $ 254.8 $ (5,506.8 ) $ 6,004.5 Crestwood Midstream Partners LP Condensed Consolidating Balance Sheet December 31, 2014 (in millions) Parent Guarantor Non- Eliminations Consolidated Assets Current assets: Cash $ — $ 7.6 $ — $ — $ 7.6 Accounts receivable 1.2 377.8 0.3 — 379.3 Inventory — 46.6 — — 46.6 Other current assets — 103.1 — 103.1 Total current assets 1.2 535.1 0.3 — 536.6 Property, plant and equipment, net 7.9 3,738.1 — — 3,746.0 Goodwill and intangible assets, net 38.0 3,166.2 — — 3,204.2 Investment in consolidated affiliates 7,148.0 — — (7,148.0 ) — Investment in unconsolidated affiliates — — 295.1 — 295.1 Other assets — 3.3 — — 3.3 Total assets $ 7,195.1 $ 7,442.7 $ 295.4 $ (7,148.0 ) $ 7,785.2 Liabilities and partners’ capital Current liabilities: Accounts payable 9.0 225.8 0.2 — 235.0 Other current liabilities 23.0 153.3 — — 176.3 Total current liabilities 32.0 379.1 0.2 — 411.3 Long-term liabilities: Long-term debt, less current portion 2,012.8 1.7 — — 2,014.5 Other long-term liabilities 1.6 36.7 — — 38.3 Deferred income taxes — 0.7 — — 0.7 Partners’ capital 5,148.7 7,024.5 123.5 (7,148.0 ) 5,148.7 Interest of non-controlling partners in subsidiaries — — 171.7 — 171.7 Total partners’ capital 5,148.7 7,024.5 295.2 (7,148.0 ) 5,320.4 Total liabilities and partners’ capital $ 7,195.1 $ 7,442.7 $ 295.4 $ (7,148.0 ) $ 7,785.2
Condensed Consolidating Statements of Operation	Crestwood Midstream Partners LP Condensed Consolidating Statement of Operations Three Months Ended March 31, 2016 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Revenues $ — $ 536.0 $ — $ — $ 536.0 Costs of product/services sold — 363.4 — — 363.4 Expenses: Operations and maintenance — 41.7 — — 41.7 General and administrative 17.7 4.5 — — 22.2 Depreciation, amortization and accretion — 64.9 — — 64.9 17.7 111.1 — — 128.8 Other operating expense: Goodwill impairment — (109.7 ) — — (109.7 ) Operating loss (17.7 ) (48.2 ) — — (65.9 ) Earnings from unconsolidated affiliates, net — — 6.5 — 6.5 Interest and debt expense, net (36.1 ) — — — (36.1 ) Equity in net income (loss) of subsidiary (41.5 ) — — 41.5 — Income (loss) before income taxes (95.3 ) (48.2 ) 6.5 41.5 (95.5 ) Benefit for income taxes — (0.2 ) — — (0.2 ) Net income (loss) (95.3 ) (48.0 ) 6.5 41.5 (95.3 ) Net income attributable to non-controlling partners in subsidiaries — — 5.9 — 5.9 Net income (loss) attributable to Crestwood Midstream Partners LP $ (95.3 ) $ (48.0 ) $ 0.6 $ 41.5 $ (101.2 ) Crestwood Midstream Partners LP Condensed Consolidating Statement of Operations Three Months Ended March 31, 2015 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Revenues $ — $ 731.5 $ — $ — $ 731.5 Costs of product/services sold — 529.7 — — 529.7 Expenses: Operations and maintenance — 50.6 — — 50.6 General and administrative 13.4 12.2 — — 25.6 Depreciation, amortization and accretion 0.2 68.6 — — 68.8 13.6 131.4 — — 145.0 Other operating expense: Loss on long-lived assets, net — (0.8 ) — — (0.8 ) Operating income (loss) (13.6 ) 69.6 — — 56.0 Earnings from unconsolidated affiliates, net — — 3.4 — 3.4 Interest and debt expense, net (29.9 ) — — — (29.9 ) Equity in net income (loss) of subsidiary 72.6 — — (72.6 ) — Income (loss) before income taxes 29.1 69.6 3.4 (72.6 ) 29.5 Provision for income taxes — 0.4 — — 0.4 Net income (loss) 29.1 69.2 3.4 (72.6 ) 29.1 Net income attributable to non-controlling partners in subsidiaries — — 5.6 — 5.6 Net income (loss) attributable to Crestwood Midstream Partners LP 29.1 69.2 (2.2 ) (72.6 ) 23.5 Net income attributable to Class A preferred units 9.2 — — — 9.2 Net income (loss) attributable to partners $ 19.9 $ 69.2 $ (2.2 ) $ (72.6 ) $ 14.3	Crestwood Midstream Partners LP Condensed Consolidating Statements of Operations Year Ended December 31, 2015 (in millions) Parent Guarantor Non- 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 expense: 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 subsidiary (1,195.9 ) — — 1,195.9 — Income (loss) before income taxes (1,410.6 ) (1,135.1 ) (60.8 ) 1,195.9 (1,410.6 ) Provision for income taxes — — — — — Net income (loss) (1,410.6 ) (1,135.1 ) (60.8 ) 1,195.9 (1,410.6 ) Net income attributable to non-controlling partners in subsidiaries — — (23.1 ) — (23.1 ) Net income (loss) attributable to Crestwood Midstream Partners LP (1,410.6 ) (1,135.1 ) (83.9 ) 1,195.9 (1,433.7 ) Net income attributable to Class A preferred units (23.1 ) — — — (23.1 ) Net income (loss) attributable to partners $ (1,433.7 ) $ (1,135.1 ) $ (83.9 ) $ 1,195.9 $ (1,456.8 ) Crestwood Midstream Partners LP Condensed Consolidating Statements of Operations Year Ended December 31, 2014 (in millions) Parent Guarantor Non- Eliminations Consolidated Revenues $ — $ 3,917.5 $ — $ — $ 3,917.5 Costs of product/services sold — 3,154.8 — — 3,154.8 Expenses: Operations and maintenance — 195.4 — — 195.4 General and administrative 49.4 42.3 — — 91.7 Depreciation, amortization and accretion 0.9 254.5 — — 255.4 50.3 492.2 — — 542.5 Other operating expense: Loss on long-lived assets, net — (35.1 ) — — (35.1 ) Goodwill impairment — (48.8 ) — — (48.8 ) Loss on contingent consideration — (8.6 ) — — (8.6 ) Operating income (loss) (50.3 ) 178.0 — — 127.7 Loss from unconsolidated affiliates, net — — (0.7 ) — (0.7 ) Interest and debt expense, net (111.4 ) — — — (111.4 ) Equity in net income (loss) of subsidiary 176.4 — — (176.4 ) — Income (loss) before income taxes 14.7 178.0 (0.7 ) (176.4 ) 15.6 Provision for income taxes — 0.9 — 0.9 Net income (loss) 14.7 177.1 (0.7 ) (176.4 ) 14.7 Net income attributable to non-controlling partners — — (16.8 ) — (16.8 ) Net income (loss) attributable to Crestwood Midstream Partners LP 14.7 177.1 (17.5 ) (176.4 ) (2.1 ) Net income attributable to Class A preferred units (17.2 ) — — — (17.2 ) Net income (loss) attributable to partners $ (2.5 ) $ 177.1 $ (17.5 ) $ (176.4 ) $ (19.3 ) Crestwood Midstream Partners Condensed Consolidating Statements of Operations Year Ended December 31, 2013 (in millions) Parent Guarantor Non- Eliminations Consolidated Revenues $ — $ 1,412.6 $ — $ — $ 1,412.6 Costs of product/services sold — 995.4 — — 995.4 Expenses: Operations and maintenance — 103.4 — — 103.4 General and administrative 46.5 37.6 — — 84.1 Depreciation, amortization and accretion 1.0 138.4 — — 139.4 47.5 279.4 — — 326.9 Other operating income (expense): Gain on long-lived assets, net — 5.3 — — 5.3 Goodwill impairment — (4.1 ) — — (4.1 ) Loss on contingent consideration — (31.4 ) — — (31.4 ) Operating income (loss) (47.5 ) 107.6 — — 60.1 Loss from unconsolidated affiliates, net — — (0.1 ) — (0.1 ) Interest and debt expense, net (68.7 ) (3.0 ) — — (71.7 ) Equity in net income (loss) of subsidiary 103.8 — — (103.8 ) — Income (loss) before income taxes (12.4 ) 104.6 (0.1 ) (103.8 ) (11.7 ) Provision for income taxes — 0.7 — — 0.7 Net income (loss) (12.4 ) 103.9 (0.1 ) (103.8 ) (12.4 ) Net income attributable to non-controlling partners — — (4.9 ) — (4.9 ) Net income (loss) attributable to Crestwood Midstream Partners LP (12.4 ) 103.9 (5.0 ) (103.8 ) (17.3 ) Net income attributable to Class A preferred units — — — — — Net income (loss) attributable to partners $ (12.4 ) $ 103.9 $ (5.0 ) $ (103.8 ) $ (17.3 )
Condensed Cash Flow Statement	Crestwood Midstream Partners LP Condensed Consolidating Statement of Cash Flows Three Months Ended March 31, 2016 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Cash flows from operating activities: $ (42.7 ) $ 172.8 $ 5.6 $ — $ 135.7 Cash flows from investing activities: Purchases of property, plant and equipment (0.9 ) (54.7 ) — — (55.6 ) Investment in unconsolidated affiliates — — (5.5 ) — (5.5 ) Proceeds from the sale of assets — 0.8 — — 0.8 Capital contributions to consolidated affiliates (3.7 ) — — 3.7 — Net cash provided by (used in) investing activities (4.6 ) (53.9 ) (5.5 ) 3.7 (60.3 ) Cash flows from financing activities: Proceeds from the issuance of long-term debt 313.5 — — — 313.5 Principal payments on long-term debt (286.0 ) — — — (286.0 ) Payments on capital leases — (0.5 ) — — (0.5 ) Payments for debt-related deferred costs (0.1 ) — — — (0.1 ) Distributions paid (97.2 ) — (3.8 ) — (101.0 ) Contributions from parent — — 3.7 (3.7 ) — Taxes paid for unit-based compensation vesting — (0.6 ) — — (0.6 ) Change in intercompany balances 117.8 (117.8 ) — — — Net cash provided by (used in) financing activities 48.0 (118.9 ) (0.1 ) (3.7 ) (74.7 ) Net change in cash 0.7 — — — 0.7 Cash at beginning of period 0.1 — — — 0.1 Cash at end of period $ 0.8 $ — $ — $ — $ 0.8 Crestwood Midstream Partners LP Condensed Consolidating Statement of Cash Flows Three Months Ended March 31, 2015 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Cash flows from operating activities: $ (54.8 ) $ 160.5 $ — $ — $ 105.7 Cash flows from investing activities: Purchases of property, plant and equipment (0.1 ) (47.3 ) — — (47.4 ) Investment in unconsolidated affiliates — — (17.9 ) — (17.9 ) Proceeds from the sale of assets — 0.5 — — 0.5 Capital contributions to consolidated affiliates (17.9 ) — — 17.9 — Other — (0.2 ) — — (0.2 ) Net cash provided by (used in) investing activities (18.0 ) (47.0 ) (17.9 ) 17.9 (65.0 ) Cash flows from financing activities: Proceeds from the issuance of long-term debt 1,114.6 — — — 1,114.6 Principal payments on long-term debt (970.4 ) — — — (970.4 ) Payments on capital leases (0.5 ) (0.2 ) — — (0.7 ) Payments for debt-related deferred costs (11.1 ) — — — (11.1 ) Distributions paid (111.4 ) — — — (111.4 ) Contributions from parent — — 17.9 (17.9 ) — Taxes paid for unit-based compensation vesting — (1.7 ) — — (1.7 ) Change in intercompany balances 51.8 (51.8 ) — — — Other (0.2 ) — — — (0.2 ) Net cash provided by (used in) financing activities 72.8 (53.7 ) 17.9 (17.9 ) 19.1 Net change in cash — 59.8 — — 59.8 Cash at beginning of period — 7.6 — — 7.6 Cash at end of period $ — $ 67.4 $ — $ — $ 67.4	Crestwood Midstream Partners LP Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2015 (in millions) Parent Guarantor Non- 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 ) Proceeds from the sale of assets — 2.7 — — 2.7 Capital distributions from unconsolidated affiliates — — 9.3 — 9.3 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 Principal 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 paid (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 Crestwood Midstream Partners LP Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2014 (in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Cash flows from operating activities: $ (165.6 ) $ 602.9 $ — $ — $ 437.3 Cash flows from investing activities: Acquisitions, net of cash acquired — (19.5 ) — — (19.5 ) Purchases of property, plant and equipment (4.3 ) (417.4 ) — — (421.7 ) Investment in unconsolidated affiliates, net — — (144.4 ) — (144.4 ) Proceeds from the sale of assets — 2.7 — — 2.7 Capital contributions to consolidated affiliates (89.5 ) — — 89.5 — Net cash provided by (used in) investing activities (93.8 ) (434.2 ) (144.4 ) 89.5 (582.9 ) Cash flows from financing activities: Proceeds from the issuance of long-term debt 2,089.9 — — — 2,089.9 Principal payments on long-term debt (1,949.8 ) (0.2 ) — — (1,950.0 ) Payments on capital leases (1.3 ) (1.9 ) — — (3.2 ) Payments for debt-related deferred costs (0.1 ) — — — (0.1 ) Distributions paid (470.5 ) — — — (470.5 ) Contributions from parents — — 89.5 (89.5 ) — Net proceeds from issuance of preferred equity of subsidiary — — 53.9 — 53.9 Net proceeds from issuance of Class A preferred units 430.5 — — — 430.5 Taxes paid for unit-based compensation vesting — (1.6 ) — — (1.6 ) Change in intercompany balances 161.4 (161.4 ) — — — Other (0.8 ) — — — (0.8 ) Net cash provided by (used in) financing activities 259.3 (165.1 ) 143.4 (89.5 ) 148.1 Net change in cash (0.1 ) 3.6 (1.0 ) — 2.5 Cash at beginning of period 0.1 4.0 1.0 — 5.1 Cash at end of period $ — $ 7.6 $ — $ — $ 7.6 Crestwood Midstream Partners LP Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2013 (in millions) Parent Guarantor Non- Eliminations Consolidated Cash flows from operating activities: $ (46.1 ) $ 333.6 $ — $ (33.8 ) $ 253.7 Cash flows from investing activities: Acquisitions, net of cash acquired — (561.5 ) — — (561.5 ) Purchases of property, plant and equipment (1.0 ) (338.3 ) — — (339.3 ) Investment in unconsolidated affiliates, net — — (151.5 ) — (151.5 ) Capital contributions to consolidated affiliates (106.4 ) — — 106.4 — Proceeds from the sale of assets — 11.2 — — 11.2 Net cash provided by (used in) investing activities (107.4 ) (888.6 ) (151.5 ) 106.4 (1,041.1 ) Cash flows from financing activities: Proceeds from the issuance of long-term debt 2,072.8 — — — 2,072.8 Principal payments on long-term debt (1,634.3 ) (0.2 ) — — (1,634.5 ) Payments on capital leases (0.4 ) (3.9 ) — — (4.3 ) Payments for debt-related deferred costs (32.0 ) — — — (32.0 ) Distributions paid (419.7 ) (33.8 ) — 33.8 (419.7 ) Contributions from parents — 55.5 56.4 (106.4 ) 5.5 Net proceeds from the issuance of common units 714.0 — — — 714.0 Net proceeds from issuance of preferred equity of subsidiary — — 96.1 — 96.1 Taxes paid for unit-based compensation vesting — (5.5 ) — — (5.5 ) Change in intercompany balances (546.8 ) 546.8 — — — Net cash provided by (used in) financing activities 153.6 558.9 152.5 (72.6 ) 792.4 Net change in cash 0.1 3.9 1.0 — 5.0 Cash at beginning of period — 0.1 — — 0.1 Cash at end of period $ 0.1 $ 4.0 $ 1.0 $ — $ 5.1

Basis of Presentation and Sum45

Basis of Presentation and Summary of Significant Accounting Policies (Detail) - USD ($) $ in Millions	3 Months Ended						12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Summary Of Significant Accounting Policies [Line Items]
Discount rate							15.00%
Impaired assets to be disposed of		$ 694.3	$ 610.8	$ 68.6		$ 83.3	$ 354.4
Deferred revenue	$ 15.7	14.2				12.2	$ 14.2	$ 12.2
Percentage of gross income from qualifying sources required to be subject to federal income tax, minimum							90.00%
Percentage Disposition Exceeded Carrying Value Of Property Plant And Equipment	30.00%
Beginning Balance	$ 1,085.5				$ 2,234.6		$ 2,234.6	2,295.1
Goodwill impairment	109.7	470.6			0		1,149.1	48.8	$ 4.1
Ending Balance	975.8	1,085.5				2,234.6	1,085.5	2,234.6	2,295.1
Deferred Finance Costs, Net	$ 39.2	40.9					40.9
Jackalope Gas Gathering Services, L.L.C.
Summary Of Significant Accounting Policies [Line Items]
Equity method investment, other than temporary impairment		51.4					51.4
Equity method investment carrying value		202.4					202.4
Powder River Basin Industrial Complex, LLC
Summary Of Significant Accounting Policies [Line Items]
Equity method investment, other than temporary impairment		23.4					23.4
Equity method investment carrying value		15.1					15.1
Natural Gas Liquids
Summary Of Significant Accounting Policies [Line Items]
Inventory		35.4				37.5	$ 35.4	37.5
Minimum
Summary Of Significant Accounting Policies [Line Items]
Discount rate	10.00%						10.00%
Maximum
Summary Of Significant Accounting Policies [Line Items]
Discount rate	19.00%						16.00%
Marcellus
Summary Of Significant Accounting Policies [Line Items]
Beginning Balance	$ 8.6				8.6		$ 8.6	8.6
Goodwill impairment	8.6						0	0
Ending Balance	0	8.6				8.6	8.6	8.6	8.6
Arrow
Summary Of Significant Accounting Policies [Line Items]
Beginning Balance	45.9				45.9		45.9	45.5
Goodwill impairment	0						0	0
Ending Balance	45.9	45.9				45.9	45.9	45.9	45.5
Northeast Storage and Transportation
Summary Of Significant Accounting Policies [Line Items]
Beginning Balance	726.3				726.3		726.3	727.1
Goodwill impairment	0						0	0
Ending Balance	726.3	726.3				726.3	726.3	726.3	727.1
COLT
Summary Of Significant Accounting Policies [Line Items]
Beginning Balance	44.9				668.3		668.3	670.5
Goodwill impairment	13.7						623.4	0
Ending Balance	31.2	44.9				668.3	44.9	668.3	670.5
Supply and Logistics
Summary Of Significant Accounting Policies [Line Items]
Beginning Balance	167.2				266.2		266.2	269.5
Goodwill impairment	65.5						99	0
Ending Balance	101.7	167.2				266.2	167.2	266.2	269.5
Storage and Terminals
Summary Of Significant Accounting Policies [Line Items]
Beginning Balance	50.5				104.2		104.2	104.7
Goodwill impairment	14.1						53.7	0
Ending Balance	36.4	50.5				104.2	50.5	104.2	104.7
US Salt
Summary Of Significant Accounting Policies [Line Items]
Beginning Balance	12.6				12.6		12.6	16.1
Goodwill impairment	0						0	2.2
Ending Balance	12.6	12.6				12.6	12.6	12.6	16.1
Trucking
Summary Of Significant Accounting Policies [Line Items]
Beginning Balance	29.5				177.9		177.9	178.4
Goodwill impairment	7.8						148.4	0
Ending Balance	21.7	29.5				177.9	29.5	177.9	178.4
Granite Wash
Summary Of Significant Accounting Policies [Line Items]
Impaired assets to be disposed of							8.5	13.2
Fair value disclosure		11.2					11.2
Impairment of intangible assets								20
Beginning Balance	0				0		0	14.2
Goodwill impairment							0	14.2
Ending Balance		0				0	0	0	14.2
Barnett
Summary Of Significant Accounting Policies [Line Items]
Impaired assets to be disposed of							354.4
Fair value disclosure		298.5					298.5
Impairment of intangible assets							238.9
Beginning Balance	0				257.2		257.2	257.2
Goodwill impairment							257.2	0
Ending Balance		0				257.2	0	257.2	257.2
Fayetteville
Summary Of Significant Accounting Policies [Line Items]
Impaired assets to be disposed of							61.9
Fair value disclosure		59.3					59.3
Impairment of intangible assets							70.9
Beginning Balance	$ 0				$ 72.5		72.5	76.8
Goodwill impairment							72.5	4.3
Ending Balance		0				$ 72.5	0	$ 72.5	$ 76.8
Haynesville
Summary Of Significant Accounting Policies [Line Items]
Impaired assets to be disposed of							45.7
Fair value disclosure		3.8					3.8
Impairment of intangible assets							6
Watkins Glen
Summary Of Significant Accounting Policies [Line Items]
Impaired assets to be disposed of							31.2
Fair value disclosure		$ 6.7					$ 6.7

Organization and Business Des46

Organization and Business Description (Narrative) (Detail) $ / shares in Units, $ in Millions	Oct. 07, 2013USD ($)shares	Jan. 31, 2016shares	Oct. 31, 2013USD ($)$ / Unit	Mar. 31, 2016Segment	Dec. 31, 2015shares	Sep. 30, 2015	Dec. 31, 2015Segment$ / sharesshares
Partnership Organization And Basis Of Presentation [Line Items]
Cash payments to unitholders upon completion of merger, per unit | $ / Unit			1.03
Cash | $	$ 34.9		$ 34.9
Conversion ratio	1.07					2.75
Distribution percentage							50.00%
Number of operating segments | Segment				3			3
Distribution Rights
Partnership Organization And Basis Of Presentation [Line Items]
Distribution declared per limited partner unit | $ / shares							$ 0.37
Crestwood Holdings
Partnership Organization And Basis Of Presentation [Line Items]
Cash | $			10
Crestwood Equity Partners LP
Partnership Organization And Basis Of Presentation [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest						99.90%	99.90%
Treasury Stock, Shares, Acquired		1,525,430			3,458,912
Crestwood Equity Partners LP | Distribution Rights
Partnership Organization And Basis Of Presentation [Line Items]
Distribution percentage						100.00%
Crestwood Gas Services GP, LLC [Member]
Partnership Organization And Basis Of Presentation [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest						0.10%	0.10%
Parent Company
Partnership Organization And Basis Of Presentation [Line Items]
Cash | $			$ 24.9
Crestwood Holdings | Majority Shareholder
Partnership Organization And Basis Of Presentation [Line Items]
Shares exchanged by acquirer	7,100,000
Crestwood Holdings | Crestwood Equity Partners LP
Partnership Organization And Basis Of Presentation [Line Items]
Shares issued by acquiree	14,300,000
Common Unit Capital | Crestwood Holdings
Partnership Organization And Basis Of Presentation [Line Items]
General partner ownership percentage							21.00%
Subordinated Unit
Partnership Organization And Basis Of Presentation [Line Items]
Units of partnership interest, amount					438,789		438,789

Basis of Presentation and Sum47

Basis of Presentation and Summary of Significant Accounting Policies (Estimated Useful Lives Of Property, Plant And Equipment) (Detail)	12 Months Ended
	Dec. 31, 2015
Gathering systems and pipelines | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	20 years
Gathering systems and pipelines | 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	20 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 contracts and easements | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	20 years
Buildings, land, rights-of-way, storage contracts 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 Sum48

Basis of Presentation and Summary of Significant Accounting Policies (Estimated Economic Lives Of Intangible Assets) (Detail)	12 Months Ended
	Dec. 31, 2015
Customer accounts
Finite-Lived Intangible Assets [Line Items]
Weighted-Average Life (years)	22 years
Covenants not to compete
Finite-Lived Intangible Assets [Line Items]
Weighted-Average Life (years)	5 years
Trademarks
Finite-Lived Intangible Assets [Line Items]
Weighted-Average Life (years)	6 years

Basis of Presentation and Sum49

Basis of Presentation and Summary of Significant Accounting Policies (Goodwill, by Reporting Unit) (Detail) - USD ($) $ in Millions	3 Months Ended			12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Goodwill [Roll Forward]
Beginning Balance	$ 1,085.5		$ 2,234.6	$ 2,234.6	$ 2,295.1
Final Purchase Price Allocation Adjustments					(11.7)
Goodwill Impairments during the Year Ended December 31, 2014	109.7	$ 470.6	0	1,149.1	48.8	$ 4.1
Ending Balance	975.8	1,085.5		1,085.5	2,234.6	2,295.1
Fayetteville
Goodwill [Roll Forward]
Beginning Balance	0		72.5	72.5	76.8
Final Purchase Price Allocation Adjustments					0
Goodwill Impairments during the Year Ended December 31, 2014				72.5	4.3
Ending Balance		0		0	72.5	76.8
Granite Wash
Goodwill [Roll Forward]
Beginning Balance	0		0	0	14.2
Final Purchase Price Allocation Adjustments					0
Goodwill Impairments during the Year Ended December 31, 2014				0	14.2
Ending Balance		0		0	0	14.2
Marcellus
Goodwill [Roll Forward]
Beginning Balance	8.6		8.6	8.6	8.6
Final Purchase Price Allocation Adjustments					0
Goodwill Impairments during the Year Ended December 31, 2014	8.6			0	0
Ending Balance	0	8.6		8.6	8.6	8.6
Arrow
Goodwill [Roll Forward]
Beginning Balance	45.9		45.9	45.9	45.5
Final Purchase Price Allocation Adjustments					0.4
Goodwill Impairments during the Year Ended December 31, 2014	0			0	0
Ending Balance	45.9	45.9		45.9	45.9	45.5
Northeast Storage and Transportation
Goodwill [Roll Forward]
Beginning Balance	726.3		726.3	726.3	727.1
Final Purchase Price Allocation Adjustments					(0.8)
Goodwill Impairments during the Year Ended December 31, 2014	0			0	0
Ending Balance	726.3	726.3		726.3	726.3	727.1
COLT
Goodwill [Roll Forward]
Beginning Balance	44.9		668.3	668.3	670.5
Final Purchase Price Allocation Adjustments					(2.2)
Goodwill Impairments during the Year Ended December 31, 2014	13.7			623.4	0
Ending Balance	31.2	44.9		44.9	668.3	670.5
West Coast
Goodwill [Roll Forward]
Beginning Balance	0		85.9	85.9	89.1
Final Purchase Price Allocation Adjustments					(3.2)
Goodwill Impairments during the Year Ended December 31, 2014				85.9	0
Ending Balance		0		0	85.9	89.1
Supply and Logistics
Goodwill [Roll Forward]
Beginning Balance	167.2		266.2	266.2	269.5
Final Purchase Price Allocation Adjustments					(3.3)
Goodwill Impairments during the Year Ended December 31, 2014	65.5			99	0
Ending Balance	101.7	167.2		167.2	266.2	269.5
Storage and Terminals
Goodwill [Roll Forward]
Beginning Balance	50.5		104.2	104.2	104.7
Final Purchase Price Allocation Adjustments					(0.5)
Goodwill Impairments during the Year Ended December 31, 2014	14.1			53.7	0
Ending Balance	36.4	50.5		50.5	104.2	104.7
US Salt
Goodwill [Roll Forward]
Beginning Balance	12.6		12.6	12.6	16.1
Final Purchase Price Allocation Adjustments					(1.3)
Goodwill Impairments during the Year Ended December 31, 2014	0			0	2.2
Ending Balance	12.6	12.6		12.6	12.6	16.1
Trucking
Goodwill [Roll Forward]
Beginning Balance	29.5		177.9	177.9	178.4
Final Purchase Price Allocation Adjustments					(0.5)
Goodwill Impairments during the Year Ended December 31, 2014	7.8			148.4	0
Ending Balance	21.7	29.5		29.5	177.9	178.4
Barnett
Goodwill [Roll Forward]
Beginning Balance	0		257.2	257.2	257.2
Final Purchase Price Allocation Adjustments					0
Goodwill Impairments during the Year Ended December 31, 2014				257.2	0
Ending Balance		0		0	257.2	257.2
Watkins Glen
Goodwill [Roll Forward]
Beginning Balance	0		66.2	66.2	94.6
Final Purchase Price Allocation Adjustments					(0.3)
Goodwill Impairments during the Year Ended December 31, 2014				66.2	28.1
Ending Balance		0		0	66.2	94.6
Crestwood Equity Partners LP
Goodwill [Roll Forward]
Beginning Balance	1,085.5		2,491.8	2,491.8	2,552.3
Final Purchase Price Allocation Adjustments					(11.7)
Goodwill Impairments during the Year Ended December 31, 2014	109.7	515.4	$ 0	1,406.3	48.8	4.1
Ending Balance	$ 975.8	$ 1,085.5		$ 1,085.5	$ 2,491.8	$ 2,552.3

Acquisitions (Narrative) (Detai

Acquisitions (Narrative) (Detail) $ in Millions	May. 09, 2014USD ($)aTractorcrude_trailerservice_vehiclesbbl	Mar. 21, 2014USD ($)double_bottom_body_tankstrailer_tanksTractorbbl	Oct. 07, 2013USD ($)	Oct. 31, 2013USD ($)shares	Jan. 31, 2013USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Nov. 08, 2013USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Oct. 08, 2013a	Jun. 19, 2013USD ($)
Business Acquisition [Line Items]
Consideration transferred					$ 258
Cash			$ 34.9	$ 34.9
Property, plant and equipment													$ 1,677.8
Goodwill						$ 2,295.1	$ 2,234.6	$ 2,295.1		$ 975.8	$ 1,085.5		1,532.7
Reduction in preliminary estimate							15.3
Marketing Supply and Logistics
Business Acquisition [Line Items]
Goodwill							713			172.4	259.8
Crestwood Equity Partners LP
Business Acquisition [Line Items]
Property, plant and equipment													2,088.1
Goodwill						2,552.3	2,491.8	2,552.3		975.8	1,085.5		$ 2,134.8
Reduction in preliminary estimate							15.3
Crestwood Equity Partners LP | Marketing Supply and Logistics
Business Acquisition [Line Items]
Goodwill							713			$ 172.4	259.8
Red Rock Transportation Inc.
Business Acquisition [Line Items]
Consideration transferred		$ 13.8
Cash		12.1
Liabilities incurred		$ 1.8
Number of trailer tanks | trailer_tanks		56
Number of Double Bottom tanks | double_bottom_body_tanks		22
Number of Tractors | Tractor		44
Crude hauling capacity, per day | bbl		28,000
Property, plant and equipment		$ 10.6
Goodwill		$ 3.2
L T Enterprises
Business Acquisition [Line Items]
Consideration transferred	$ 10.7
Cash	9
Liabilities incurred	$ 1.7
Number of Tractors | Tractor	38
Crude hauling capacity, per day | bbl	20,000
Number of Crude Trailers | crude_trailer	51
Number of Service Vehicles | service_vehicles	17
Land (in acres) | a	20
Inergy Midstream
Business Acquisition [Line Items]
Goodwill							1,532.7
Reduction in preliminary estimate								15.3
Revenue of acquiree since acquisition date						902.6
Operating income of acquiree since acquisition date						32.8
Transaction costs						24.7	2.1	24.7
Inergy Midstream | Marketing Supply and Logistics
Business Acquisition [Line Items]
Goodwill							138.1
Inergy Midstream | Storage And Transportation
Business Acquisition [Line Items]
Goodwill							1,394.6
Inergy Midstream | Crestwood Equity Partners LP
Business Acquisition [Line Items]
Goodwill							2,134.8
Revenue of acquiree since acquisition date						916.7
Operating income of acquiree since acquisition date						23.9
Transaction costs						$ 30.1	3.4	$ 30.1
Inergy Midstream | Crestwood Equity Partners LP | Marketing Supply and Logistics
Business Acquisition [Line Items]
Goodwill							740.2
Inergy Midstream | Crestwood Equity Partners LP | Storage And Transportation
Business Acquisition [Line Items]
Goodwill							1,394.6
Arrow Midstream Holdings, LLC
Business Acquisition [Line Items]
Consideration transferred									$ 750
Cash				$ 550
Property, plant and equipment									400.5
Goodwill									45.9
Revenue of acquiree since acquisition date							218.8
Operating income of acquiree since acquisition date							1.7
Transaction costs							$ 1.2				$ 5.4
Other consideration transferred									$ 11.3
Common units in acquisition | shares				8,826,125
Central delivery point acquired (in acres) | a												23,000,000

Acquisitions (Assets Acquired,

Acquisitions (Assets Acquired, Liabilities Assumed) (Detail) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Nov. 08, 2013	Jun. 19, 2013
Change in Accounting Estimate [Line Items]
Current assets						$ 49.1
Property, plant and equipment						1,677.8
Intangible assets						196
Other assets						2.9
Total identifiable assets acquired						1,925.8
Current liabilities						30.9
Long-term debt						745
Assets retirement obligations		$ 26.4	$ 23.8	$ 15.1
Other long-term liabilities						5.3
Total liabilities assumed						781.2
Net identifiable assets acquired						1,144.6
Goodwill	$ 975.8	1,085.5	2,234.6	2,295.1		1,532.7
Net assets acquired						2,677.3
Arrow Midstream Holdings, LLC
Change in Accounting Estimate [Line Items]
Current assets					$ 192.7
Property, plant and equipment					400.5
Intangible assets					323.4
Other assets					19.5
Total identifiable assets acquired					936.1
Current liabilities					215.8
Assets retirement obligations					1.2
Other long-term liabilities					3.7
Total liabilities assumed					220.7
Net identifiable assets acquired					715.4
Goodwill					45.9
Net assets acquired					$ 761.3
Crestwood Equity Partners LP
Change in Accounting Estimate [Line Items]
Current assets						224.5
Property, plant and equipment						2,088.1
Intangible assets						337.5
Other assets						12.7
Total identifiable assets acquired						2,662.8
Current liabilities						207.6
Long-term debt						1,079.3
Other long-term liabilities						146.6
Total liabilities assumed						1,433.5
Net identifiable assets acquired						1,229.3
Goodwill	$ 975.8	$ 1,085.5	$ 2,491.8	$ 2,552.3		2,134.8
Net assets acquired						$ 3,364.1

Acquisitions (Pro Forma Revenue

Acquisitions (Pro Forma Revenues) (Detail) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended									12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Crestwood Equity Partners LP
Business Acquisition [Line Items]
Net income per limited partner unit: Basic	$ (1.47)	$ (20.77)	$ (11.78)	$ (2.14)	$ 0.44	$ 2.06	$ 0.15	$ (0.24)	$ 1.05	$ (54)	$ 3.03	$ 0.59
Net income per limited partner unit: Diluted	$ (1.47)	$ (20.77)	$ (11.76)	$ (2.14)	$ 0.44	$ 2.06	$ 0.15	$ (0.24)	$ 1.05	$ (54)	$ 3.03	$ 0.59
Rangeland Energy LLC
Business Acquisition [Line Items]
Revenues											$ 3,423.8
Net income (loss)											(5)
Rangeland Energy LLC | Crestwood Equity Partners LP
Business Acquisition [Line Items]
Revenues											3,449.3
Net income (loss)											$ 3.9
Net income per limited partner unit: Basic											$ 0.40
Net income per limited partner unit: Diluted											$ 0.40

Certain Balance Sheet Informa53

Certain Balance Sheet Information (Property, Plant And Equipment) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Mar. 31, 2016
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	$ 4,077.7	$ 4,144.6		$ 4,095.7
Less: accumulated depreciation and depletion	552	398.6		581.3
Property, plant and equipment, net	3,525.7	3,746		3,514.4
Depreciation	186.7	170.9	$ 99.9
Depletion	0.7	0.7	0.4
Interest Costs Capitalized	2.5	7.5	3.4
Capital Leased Assets, Gross	2.4	5.3
Gathering systems and pipelines
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	1,213.2	1,279.5
Facilities and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	1,691	1,653.8
Buildings, land, rights-of-way, storage contracts and easements
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	837.1	840
Vehicles
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	44.6	43.5
Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	114.5	156.5
Base gas
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	37.3	37.5
Salt deposits
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	120.5	120.5
Office furniture and fixtures
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	19.5	13.3
Crestwood Equity Partners LP
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	3,747.7	4,273.9		3,765.7
Less: accumulated depreciation and depletion	436.9	380.1		462.7
Property, plant and equipment, net	3,310.8	3,893.8		$ 3,303
Depreciation	195.1	184.2	109.9
Interest Costs Capitalized	2.5	7.7	$ 3.4
Crestwood Equity Partners LP | Gathering systems and pipelines
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	1,070.4	1,410.9
Crestwood Equity Partners LP | Facilities and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	1,505.9	1,648.3
Crestwood Equity Partners LP | Buildings, land, rights-of-way, storage contracts and easements
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	833.4	841.5
Crestwood Equity Partners LP | Vehicles
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	46.3	45.2
Crestwood Equity Partners LP | Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	114.5	156.5
Crestwood Equity Partners LP | Base gas
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	37.3	37.5
Crestwood Equity Partners LP | Salt deposits
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	120.5	120.5
Crestwood Equity Partners LP | Office furniture and fixtures
Property, Plant and Equipment [Line Items]
Property, plant and equipment (Note 4)	$ 19.4	$ 13.5

Certain Balance Sheet Informa54

Certain Balance Sheet Information (Intangible Assets) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Mar. 31, 2016
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	$ 1,022.6	$ 1,123.7
Less: accumulated amortization	197.9	154.1		$ 216
Amortization of Intangible Assets and Interest Expense	100	92.1	$ 49
Total intangible assets, net	802.3	969.6
Customer accounts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	583.7	583.7
Less: accumulated amortization	130.1	72.5
Covenants not to compete
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	5.6	8.6
Less: accumulated amortization	1.7	2.6
Gathering systems and pipelines
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	325.2	431.4
Less: accumulated amortization	44.3	47.9
Acquired storage contracts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	29	29
Less: accumulated amortization	18.5	12.7
Trademarks
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	15.8	16.7
Less: accumulated amortization	3.3	2
Deferred financing and other costs
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	63.3	54.3
Less: accumulated amortization	22.4	16.4
Scenario, Previously Reported
Finite-Lived Intangible Assets [Line Items]
Less: accumulated amortization	220.3
Crestwood Equity Partners LP
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	1,039.1	1,441.9
Less: accumulated amortization	206.6	210.6		$ 225.6
Amortization of Intangible Assets and Interest Expense	114	109.8	$ 66.7
Total intangible assets, net	810.1	1,231.3
Crestwood Equity Partners LP | Customer accounts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	583.7	583.7
Less: accumulated amortization	130.1	72.5
Crestwood Equity Partners LP | Covenants not to compete
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	6.6	9.6
Less: accumulated amortization	2.5	3.2
Crestwood Equity Partners LP | Gathering systems and pipelines
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	325.2	730.2
Less: accumulated amortization	44.3	98
Crestwood Equity Partners LP | Acquired storage contracts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	29	29
Less: accumulated amortization	18.5	12.7
Crestwood Equity Partners LP | Trademarks
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	31.3	32.2
Less: accumulated amortization	11.2	6.7
Crestwood Equity Partners LP | Deferred financing and other costs
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	63.3	57.2
Less: accumulated amortization	22.4	$ 17.5
Crestwood Equity Partners LP | Scenario, Previously Reported
Finite-Lived Intangible Assets [Line Items]
Less: accumulated amortization	$ 229

Certain Balance Sheet Informa55

Certain Balance Sheet Information (Amortization and Interest Expense, Fiscal Year Maturity) (Detail) $ in Millions	Dec. 31, 2015USD ($)
Finite-Lived Intangible Assets [Line Items]
2,016	$ 79.6
2,017	66.7
2,018	55.9
2,019	53.8
2,020	52.6
Crestwood Equity Partners LP
Finite-Lived Intangible Assets [Line Items]
2,016	82.9
2,017	69.8
2,018	57.4
2,019	53.8
2,020	$ 52.6

Certain Balance Sheet Informa56

Certain Balance Sheet Information (Accrued Expenses and Other Liabilities) (Detail) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	$ 29	$ 44.1	$ 50
Accrued property taxes	5.4	4.8	2.2
Accrued product purchases payable	1.4	1.5	0.7
Tax payable	0.8	0.5	1.2
Interest payable	35.6	26.2	21.9
Accrued additions to property, plant and equipment	5.3	10.4	20
Commitments and contingent liabilities		0	40
Capital leases	1.4	1.6	1.9
Deferred revenue	15.7	14.2	12.2
Total accrued expenses and other liabilities	94.6	103.3	150.1
Crestwood Equity Partners LP
Accrued Expenses and Other Liabilities [Line Items]
Accrued expenses	30.7	46.4	52.5
Accrued property taxes	5.4	4.8	2.2
Accrued product purchases payable	1.4	1.5	0.7
Tax payable	1.3	0.5	1.6
Interest payable	35.6	26.2	23.5
Accrued additions to property, plant and equipment	5.3	10.4	20
Commitments and contingent liabilities		0	40
Capital leases	1.4	1.6	1.9
Deferred revenue	15.7	14.2	12.2
Total accrued expenses and other liabilities	$ 96.8	$ 105.6	$ 154.6

Asset Retirement Obligations (D

Asset Retirement Obligations (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Net asset retirement obligation at January 1	$ 23.8	$ 15.1
Liabilities incurred	1.1	4.6
Acquisitions	0	1.2
Accretion expense	1.5	1.1
Changes in estimate	0	1.8
Net asset retirement obligation at December 31	$ 26.4	$ 23.8

Investments in Unconsolidated58

Investments in Unconsolidated Affiliates (Net Investments In and Earnings (Loss) from Unconsolidated Affiliates) (Detail) - USD ($) $ in Millions	3 Months Ended									12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Sep. 04, 2013
Schedule of Equity Method Investments [Line Items]
Investment	$ 260.6	$ 254.3			$ 254.3	$ 295.1				$ 254.3	$ 295.1
Earnings from unconsolidated affiliates, net	$ 6.5	$ (72)	$ 2.8	$ 5	3.4	0.6	$ 0.3	$ (1.5)	$ (0.1)	$ (60.8)	(0.7)	$ (0.1)
Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Ownership Percentage	50.00%	50.00%								50.00%
Investment	$ 202.4	$ 202.4			202.4	232.9				$ 202.4	232.9
Earnings from unconsolidated affiliates, net	5.1				2.5					(43.4)	0.5	0.1
Difference between carrying amount and underlying equity	0.9	$ 0.9								0.9
Amortization	$ 0.1				0.8					3	3.1	1.4
Equity method investment, other than temporary impairment										$ 51.4
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Ownership Percentage	50.01%	50.01%								50.01%
Investment	$ 43.1	$ 36.8			36.8	36				$ 36.8	36
Earnings from unconsolidated affiliates, net	0.8				0.9					2.5	0.2	0
Difference between carrying amount and underlying equity	28.8	$ 29.1								29.1
Amortization	$ 0.3				0.3					$ 1.3	0.1
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Ownership Percentage	50.01%	50.01%								50.01%			50.00%
Investment	$ 15.1	$ 15.1			15.1	$ 26.2				$ 15.1	26.2
Earnings from unconsolidated affiliates, net	0.6				$ 0					(19.9)	$ (1.4)	$ (0.2)
Difference between carrying amount and underlying equity	23	$ 23.4								23.4
Amortization	$ 0.4
Income (loss) from Equity Method Investments, Capital Adjustment										3.2
Equity method investment, other than temporary impairment										$ 23.4

Investments in Unconsolidated59

Investments in Unconsolidated Affiliates Narrative (Detail) $ in Millions, ft³ in Billions	May. 05, 2016USD ($)	Oct. 07, 2013USD ($)	Sep. 04, 2013USD ($)	Apr. 30, 2016USD ($)	Feb. 29, 2016USD ($)	Jan. 31, 2016USD ($)	Dec. 31, 2014USD ($)	Oct. 31, 2013USD ($)	Mar. 31, 2016USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2015USD ($)miinSystemft³	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated affiliates in period									$ 5.5	$ 17.9	$ 41.8	$ 144.4	$ 151.5
Total cash consideration, paid		$ 34.9						$ 34.9
Gain (loss) on long-lived assets, net									0	(0.8)	227.8	35.1	(5.3)
Investments in unconsolidated affiliates (Note 6)							$ 295.1		260.6	254.3	254.3	295.1
Related Party Transaction, Expenses from Transactions with Related Party									$ 0.7	0.9	$ 2.8	0.2	0
Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated affiliates in period							107.5
Equity method ownership percentage									50.00%		50.00%
Investments in unconsolidated affiliates (Note 6)							232.9		$ 202.4	202.4	$ 202.4	232.9
Proceeds from Equity Method Investment, Dividends or Distributions					$ 5.1				5.1		$ 12.5
Jackalope Gas Gathering Services, L.L.C. | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Dividends or Distributions	$ 7
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated affiliates in period							66.4		$ 5.5	5.7
Equity method ownership percentage									50.01%		50.01%
Total cash consideration, paid							132.8
Gain (loss) on long-lived assets, net							30.6					30.6
Investments in unconsolidated affiliates (Note 6)							36		$ 43.1	36.8	$ 36.8	36
Miles of pipeline | mi											63
Diameter of pipeline | in											24
Number of pipeline systems | System											10
Proceeds from Equity Method Investment, Dividends or Distributions											$ 7.4
Tres Palacios Holdings LLC | Tres Palacios North Pipeline Lateral
Schedule of Equity Method Investments [Line Items]
Miles of pipeline | mi											52
Tres Palacios Holdings LLC | Tres Palacios South Pipeline Lateral
Schedule of Equity Method Investments [Line Items]
Miles of pipeline | mi											11
Tres Palacios Holdings LLC | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Proceeds from Equity Method Investment, Dividends or Distributions				$ 4.1
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated affiliates in period										3.7	$ 10.7	3.4
Equity method ownership percentage			50.00%						50.01%		50.01%
Investments in unconsolidated affiliates (Note 6)							26.2		$ 15.1	15.1	$ 15.1	26.2
Proceeds from Equity Method Investment, Dividends or Distributions						$ 0.6			0.6	0.3	$ 1.9
Brookfield Infrastructure Group [Member] | Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership percentage											49.99%
Crestwood Equity Partners LP
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated affiliates in period									5.5	18.1	$ 42	108.6	151.5
Gain (loss) on long-lived assets, net									0	(1)	821.2	1.9	(5.3)
Investments in unconsolidated affiliates (Note 6)							295.1		260.6		254.3	295.1
Related Party Transaction, Expenses from Transactions with Related Party									$ 0.1	0.1	$ 0.4	0.5	$ 25.3
Crestwood Equity Partners LP | Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates (Note 6)							$ 35.8					35.8
Tres Palacios Storage Company L L C [Member]
Schedule of Equity Method Investments [Line Items]
Storage capacity | ft³											38.4
Related Party Transaction, Expenses from Transactions with Related Party											$ 2.8	0.2
Crude Logistics L L C [Member] | Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated affiliates in period			$ 22.5
Crestwood Niobrara LLC | Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated affiliates in period										$ 8.8	25.4	$ 105.2
Crestwood Niobrara LLC | Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated affiliates in period											$ 5.7

Risk Management (Narrative) (De

Risk Management (Narrative) (Detail) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivative [Line Items]
Collateral posted for commodity derivative instruments	$ 7.1		$ 16.8	$ 33.6
Price Risk Contracts | Maximum
Derivative [Line Items]
Remaining maturity	36 months		36 months
Percent of contracts expiring in next twelve months	81.00%		84.00%
Commodity contract
Derivative [Line Items]
Gain (Loss) on derivative instruments not designated as hedging	$ 1.2	$ 2.9	$ 18.9	51.2	$ 11.2
Aggregate fair value of commodity derivative instruments			3.3	5.2
Collateral posted for commodity derivative instruments	0.3			1.8
Commodity Contract With Credit Contingent Features
Derivative [Line Items]
Aggregate fair value of commodity derivative instruments	3.8		3.3
NYMEX Derivative Liability
Derivative [Line Items]
Aggregate fair value of commodity derivative instruments	3.1		20.8	36.9
NYMEX Margin Deposit
Derivative [Line Items]
NYMEX margin deposits	$ 9.5		$ 26.7	$ 41.9

Risk Management (Notional Amoun

Risk Management (Notional Amounts and Terms of Company's Derivative Financial Instruments) (Detail) - bbl bbl in Millions	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Propane, crude and heating oil (barrels) | Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount	10.6	9.1	6.8
Propane, crude and heating oil (barrels) | Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount	11.9	10.9	8.4
Natural gas (MMBTU's) | Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount		0	0.2
Natural gas (MMBTU's) | Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount		0	0.1

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule of Carrying Values and Estimated Fair Values of Senior Notes) (Detail) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Carrying amount		$ 0	$ 350
Crestwood Equity Partners LP
Debt Instrument [Line Items]
Carrying amount		0	11.4
Fair value		0	11.6
Senior Notes, 2020
Debt Instrument [Line Items]
Carrying amount	$ 503.2	503.3	504
Fair value	399.8	382.3	481.6
Senior Notes, 2022
Debt Instrument [Line Items]
Carrying amount	600	600	600
Fair value	446	437.4	568.5
Senior Notes, 2023
Debt Instrument [Line Items]
Carrying amount	700	700	0
Fair value	$ 519.8	491.8	0
Senior Notes 2019
Debt Instrument [Line Items]
Carrying amount		0	351
Fair value		$ 0	$ 360.5

Fair Value Measurements (Assets

Fair Value Measurements (Assets And Liabilities Measured At Fair Value On Recurring Basis) (Detail) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	$ 32.6	$ 58.3	$ 147.2
SPH units	4.2	3.4	6.1
Assets, Fair Value Disclosure, Excluding Netting Adjustments	36.8	61.7	153.3
Liabilities from price risk management	26.8	41.5	100.8
Interest rate swaps(3)			1.6
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	26.8	41.5	102.4
Netting agreements	(19.7)	(13.7)	(28.8)
Derivative Asset, Fair Value of Collateral	1.5	(12)	(38.6)
Assets from price risk management, total	14.4	32.6	79.8
Total assets at fair value	18.6	36	85.9
Netting agreements	(19.7)	(13.7)	(28.8)
Derivative Liability, Fair Value of Collateral	0.2	(20.4)	(46.6)
Liabilities from price risk management, total	7.3	7.4	27
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	0.4	0.5	0.5
SPH units	4.2	3.4	6.1
Assets, Fair Value Disclosure, Excluding Netting Adjustments	4.6	3.9	6.6
Liabilities from price risk management	0.2	0.2	1.6
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	0.2	0.2	1.6
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	32.2	57.8	146.7
Assets, Fair Value Disclosure, Excluding Netting Adjustments	32.2	57.8	146.7
Liabilities from price risk management	26.6	41.3	99.2
Interest rate swaps(3)			1.6
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	26.6	41.3	100.8
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	0	0	0
SPH units	0	0	0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	0	0	0
Liabilities from price risk management	0	0	0
Interest rate swaps(3)			0
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	$ 0	$ 0	$ 0

Long-Term Debt (Components Of L

Long-Term Debt (Components Of Long-Term Debt) (Detail) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Senior notes		$ 0	$ 350
Premium on Crestwood Midstream 2019 Senior Notes		0	1
Deferred Finance Costs, Net	$ 39.2	40.9
Total Crestwood Equity debt	2,531.7	2,502.7	2,015.3
Other	0	0.2	0.8
Less: current portion	0.9	0.9	0.8
Total long-term debt, less current portion	2,530.8	2,501.8	2,014.5
Scenario, Previously Reported
Debt Instrument [Line Items]
Total Crestwood Equity debt		2,543.6
Total long-term debt, less current portion		2,542.7
Senior Notes, 2020
Debt Instrument [Line Items]
Senior notes	503.2	503.3	504
Senior Notes, 2022
Debt Instrument [Line Items]
Senior notes	600	600	600
Senior Notes, 2023
Debt Instrument [Line Items]
Senior notes	700	700	0
Senior Notes | Senior Notes, 2020
Debt Instrument [Line Items]
Senior notes	500	500	500
Senior Notes | Senior Notes, 2022
Debt Instrument [Line Items]
Senior notes	600	600	600
Senior Notes | Senior Notes, 2023
Debt Instrument [Line Items]
Senior notes	700	700	0
Fair value adjustment of 2020 Senior Notes | Senior Notes, 2020
Debt Instrument [Line Items]
Fair value adjustment	3.2	3.3	4
Other
Debt Instrument [Line Items]
Other	4.9	5.3	5.3
CEQP Senior Notes | CEQP Senior Notes
Debt Instrument [Line Items]
Senior notes		0	11.4
Crestwood Equity Partners LP
Debt Instrument [Line Items]
Senior notes		0	11.4
Total Crestwood Equity debt	2,531.7	2,502.9	2,396.5
Less: current portion	0.9	1.1	3.7
Total long-term debt, less current portion	2,530.8	2,501.8	2,392.8
Crestwood Equity Partners LP | Scenario, Previously Reported
Debt Instrument [Line Items]
Total Crestwood Equity debt		2,543.8
Total long-term debt, less current portion		2,542.7
Revolving Credit Facility | Crestwood Midstream Revolver
Debt Instrument [Line Items]
Credit agreement outstanding carrying value	$ 762.8	735	555
Revolving Credit Facility | Line of Credit | CEQP Credit Facility
Debt Instrument [Line Items]
Credit agreement outstanding carrying value		$ 0	$ 369

Long-Term Debt (Narrative) (Det

Long-Term Debt (Narrative) (Detail)	Feb. 12, 2016USD ($)	Nov. 13, 2015USD ($)	Aug. 14, 2015USD ($)	May. 15, 2015USD ($)	Apr. 08, 2015USD ($)	Feb. 13, 2015USD ($)	Nov. 14, 2014USD ($)	Aug. 14, 2014USD ($)	May. 15, 2014USD ($)	Feb. 14, 2014USD ($)	Nov. 14, 2013USD ($)	Aug. 14, 2013USD ($)	Aug. 09, 2013USD ($)	May. 10, 2013USD ($)	Feb. 12, 2013USD ($)	Sep. 30, 2015USD ($)	Mar. 31, 2016USD ($)	Mar. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Feb. 28, 2015USD ($)swap_agreement
Debt Instrument [Line Items]
Gains (Losses) on Extinguishment of Debt																				$ 18,900,000	$ 0	$ 0
Gain (Loss) on Hedging Activity																				500,000	2,700,000	1,700,000
Distribution Made to Limited Partner, Cash Distributions Paid			$ 74,300,000	$ 74,300,000		$ 74,300,000	$ 74,100,000	$ 74,100,000	$ 74,200,000	$ 74,100,000	$ 69,500,000	$ 34,300,000	$ 27,400,000	$ 27,400,000	$ 21,000,000		$ 97,200,000	$ 26,600,000		$ 222,900,000	296,500,000	179,600,000
Senior Secured Leverage Ratio, maximum																	3.75			3.75
Senior Secured Leverage Ratio																	1.48			1.37
Early Repayment of Senior Debt																				$ 13,600,000	0	0
Senior notes																				$ 0	350,000,000
Financial Guarantee [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage																				7.50%
Guarantor Obligations, Maximum Exposure, Undiscounted																				$ 497,000,000
Crestwood Equity Partners LP
Debt Instrument [Line Items]
Gains (Losses) on Extinguishment of Debt																				20,000,000	0	0
Distribution Made to Limited Partner, Cash Distributions Paid	$ 95,600,000	$ 94,300,000	$ 25,700,000	$ 25,700,000		$ 25,800,000	$ 25,600,000	$ 25,600,000	$ 25,700,000	$ 25,600,000	$ 25,000,000	$ 22,300,000				$ 378,300,000			$ 378,300,000	171,500,000	102,500,000	47,300,000
Early Repayment of Senior Debt																				(13,600,000)	0	$ 0
Senior notes																				$ 0	11,400,000
Interest Rate Swap Maturing 2016
Debt Instrument [Line Items]
Fixed rate, range low end																				0.84%
Fixed rate, range high end																				2.35%
Revolving Loan Facility
Debt Instrument [Line Items]
Credit agreement outstanding carrying value																				$ 1,500,000,000	1,000,000,000
Senior Notes | Crestwood Equity Partners LP
Debt Instrument [Line Items]
Restricted net assets																				2,981,600,000
Minimum | Crestwood Midstream Credit Facility
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Amount																				0.0030
Maximum | Crestwood Midstream Credit Facility
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Amount																				$ 0.0050
Revolving Credit Facility | Crestwood Midstream Revolver | Federal Funds Rate
Debt Instrument [Line Items]
Variable interest rate																				0.50%
Revolving Credit Facility | Crestwood Midstream Revolver | Eurodollar [Member]
Debt Instrument [Line Items]
Variable interest rate																				1.00%
Revolving Credit Facility | Minimum | Crestwood Midstream Revolver | Eurodollar [Member]
Debt Instrument [Line Items]
Variable interest rate																				0.75%
Revolving Credit Facility | Minimum | Crestwood Midstream Credit Facility | Eurodollar [Member]
Debt Instrument [Line Items]
Variable interest rate																				1.75%
Revolving Credit Facility | Maximum | Crestwood Midstream Revolver | Eurodollar [Member]
Debt Instrument [Line Items]
Variable interest rate																				1.75%
Revolving Credit Facility | Maximum | Crestwood Midstream Credit Facility | Eurodollar [Member]
Debt Instrument [Line Items]
Variable interest rate																				2.75%
CEQP Credit Facility
Debt Instrument [Line Items]
Gains (Losses) on Extinguishment of Debt																900,000				$ 200,000
Crestwood Midstream Revolver
Debt Instrument [Line Items]
Gains (Losses) on Extinguishment of Debt																			$ 1,800,000
CEQP Credit Facility | Interest Rate Swap [Member]
Debt Instrument [Line Items]
Number of interest rate derivatives held | swap_agreement																							5
Aggregate notional amount, cash flow hedges																							$ 175,000,000
CEQP Credit Facility | Revolving Credit Facility | Credit Agreement
Debt Instrument [Line Items]
Letters of credit outstanding																					56,700,000
CEQP Credit Facility | Revolving Credit Facility | Line of Credit
Debt Instrument [Line Items]
Credit agreement outstanding carrying value																				0	$ 369,000,000
CEQP Credit Facility | Revolving Credit Facility | Line of Credit | Amended And Restated
Debt Instrument [Line Items]
Credit agreement outstanding carrying value																				495,000,000
CEQP Credit Facility | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate																					2.91%
CEQP Credit Facility | Revolving Credit Facility | Minimum | London Interbank Offered Rate
Debt Instrument [Line Items]
Weighted average interest rate																					3.02%
CEQP Credit Facility | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate																					5.00%
Crestwood Midstream Credit Facility
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity																				350,000,000
Crestwood Midstream Revolver
Debt Instrument [Line Items]
Credit agreement outstanding carrying value																	$ 1,000,000,000			$ 1,000,000,000
Consolidated Leverage Ratio Maximum																	5.50			5.50
Crestwood Midstream Revolver | Revolving Credit Facility
Debt Instrument [Line Items]
Letters of credit outstanding																	$ 60,700,000			$ 62,200,000	$ 15,100,000
Debt, Weighted Average Interest Rate																	2.96%			2.70%	2.86%
Credit agreement outstanding carrying value																	$ 762,800,000			$ 735,000,000	$ 555,000,000
Debt Instrument, Unused Borrowing Capacity, Amount																	$ 268,200,000			$ 399,000,000
Interest Coverage Ratio Minimum																	2.50			2.50
Total funded debt to consolidated EBITDA																	4.98			4.75
Consolidated EBITDA to consolidated interest expense																	3.77			3.99
Crestwood Midstream Revolver | Revolving Credit Facility | Line of Credit
Debt Instrument [Line Items]
Proceeds from Issuance of Debt					$ 315,000,000											$ 720,000,000
Crestwood Midstream Revolver | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate																	2.94%			2.70%	2.66%
Crestwood Midstream Revolver | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate																	5.00%			5.00%	4.75%
Crestwood Midstream Revolver | Bridge Loan
Debt Instrument [Line Items]
Credit agreement outstanding carrying value																				$ 25,000,000
Senior Notes 2019
Debt Instrument [Line Items]
Gains (Losses) on Extinguishment of Debt																				(17,100,000)
Senior notes																				0	$ 351,000,000
Senior Notes 2019 | Senior Notes
Debt Instrument [Line Items]
Long-term Debt																				$ 350,000,000
Debt Instrument, Interest Rate, Stated Percentage																				7.75%
Early Repayment of Senior Debt					364,100,000
Interest Paid					500,000
Call Premium On Debt Redemption					$ 13,600,000
Senior Notes, 2020
Debt Instrument [Line Items]
Senior notes																	$ 503,200,000			$ 503,300,000	504,000,000
Senior Notes, 2020 | Senior Notes
Debt Instrument [Line Items]
Long-term Debt																				$ 500,000,000
Debt Instrument, Interest Rate, Stated Percentage																				6.00%
Senior notes																	500,000,000			$ 500,000,000	500,000,000
Senior Notes, 2022
Debt Instrument [Line Items]
Senior notes																	600,000,000			600,000,000	600,000,000
Senior Notes, 2022 | Senior Notes
Debt Instrument [Line Items]
Long-term Debt																				$ 600,000,000
Debt Instrument, Interest Rate, Stated Percentage																				6.125%
Senior notes																	600,000,000			$ 600,000,000	600,000,000
Senior Notes, 2023
Debt Instrument [Line Items]
Senior notes																	700,000,000			700,000,000	0
Senior Notes, 2023 | Senior Notes
Debt Instrument [Line Items]
Proceeds from Issuance of Debt																	$ 688,300,000			$ 688,300,000
Debt Instrument, Interest Rate, Stated Percentage																	6.25%			6.25%
Senior notes																	$ 700,000,000			$ 700,000,000	0
Obligations Under Noncompetition Agreements And Notes To Former Owners Of Businesses Acquired
Debt Instrument [Line Items]
Total payments due																				6,600,000	6,500,000
Obligations under noncompete agreements, unamortized discount																				1,300,000	1,200,000
Obligations Under Noncompetition Agreements And Notes To Former Owners Of Businesses Acquired | Crestwood Equity Partners LP
Debt Instrument [Line Items]
Total payments due																				6,800,000	$ 7,400,000
Obligations under noncompete agreements, unamortized discount																				$ 1,300,000
Obligations Under Noncompetition Agreements And Notes To Former Owners Of Businesses Acquired | Minimum
Debt Instrument [Line Items]
Inputed interest																				5.02%
Obligations Under Noncompetition Agreements And Notes To Former Owners Of Businesses Acquired | Minimum | Crestwood Equity Partners LP
Debt Instrument [Line Items]
Inputed interest																				5.02%
Obligations Under Noncompetition Agreements And Notes To Former Owners Of Businesses Acquired | Maximum
Debt Instrument [Line Items]
Inputed interest																				8.00%
Obligations Under Noncompetition Agreements And Notes To Former Owners Of Businesses Acquired | Maximum | Crestwood Equity Partners LP
Debt Instrument [Line Items]
Inputed interest																				8.00%

Long-Term Debt (Maturities of L

Long-Term Debt (Maturities of Long Term Debt) (Detail) $ in Millions	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
2,016	$ 0.9
2,017	1
2,018	1
2,019	1.1
2,020	1,238.6
Thereafter	1,301
Total debt	2,543.6
Crestwood Equity Partners LP
Debt Instrument [Line Items]
2,016	1.1
2,017	1
2,018	1
2,019	1.1
2,020	1,238.6
Thereafter	1,301
Total debt	$ 2,543.8

Earnings Per Limited Partner 67

Earnings Per Limited Partner Unit (Detail) - shares	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Preferred Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Units excluded from dilutive earnings per share	6,212,256	1,547,060
Preferred Units | Crestwood Niobrara LLC
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Units excluded from dilutive earnings per share	19,262,780	2,760,794
Subordinated Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Units excluded from dilutive earnings per share	438,789	438,789

Income Taxes (Detail)

Income Taxes (Detail) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current:
Federal			$ 0	$ 0	$ 0
State			0.3	0.2	0.7
Total current			0.3	0.2	0.7
Deferred:
Federal			0	0	0
State			(0.3)	0.7	0
Total deferred	$ 0.2	$ 0.1	(0.3)	0.7	0
Provision (benefit) for income taxes	(0.2)	0.4	0	0.9	0.7
Basis difference in stock of company			0	0
Total deferred tax asset			0	0
Deferred tax liability:
Basis difference in stock of acquired company			(0.4)	(0.7)
Total deferred tax liability			(0.4)	(0.7)
Net deferred tax liability			(0.4)	(0.7)
Crestwood Equity Partners LP
Current:
Federal			1.6	5	2.5
State			0.6	1.3	1.3
Total current			2.2	6.3	3.8
Deferred:
Federal			(2.9)	(5.3)	(2.5)
State			(0.7)	0.1	(0.3)
Total deferred	(0.1)	(0.9)	(3.6)	(5.2)	(2.8)
Provision (benefit) for income taxes	$ 0	$ 0.4	(1.4)	1.1	$ 1
Basis difference in stock of company			0.5	0
Total deferred tax asset			0.5	0
Deferred tax liability:
Basis difference in stock of acquired company			(8.9)	(12)
Total deferred tax liability			(8.9)	(12)
Net deferred tax liability			$ (8.4)	$ (12)

Partners' Capital (Narrative) (

Partners' Capital (Narrative) (Detail)	Apr. 21, 2016$ / sharesshares	Feb. 12, 2016USD ($)$ / sharesshares	Feb. 05, 2016	Nov. 13, 2015USD ($)	Nov. 06, 2015	Aug. 14, 2015USD ($)	Aug. 10, 2015USD ($)	Aug. 07, 2015	May. 15, 2015USD ($)	May. 08, 2015	Feb. 13, 2015USD ($)	Feb. 06, 2015	Jan. 30, 2015shares	Nov. 14, 2014USD ($)	Nov. 07, 2014	Aug. 14, 2014USD ($)	Aug. 07, 2014	Jun. 17, 2014USD ($)$ / shares	May. 15, 2014USD ($)	May. 08, 2014	Feb. 14, 2014USD ($)	Feb. 07, 2014	Nov. 14, 2013USD ($)	Nov. 08, 2013shares	Nov. 07, 2013		Oct. 07, 2013USD ($)shares	Aug. 14, 2013USD ($)	Aug. 09, 2013USD ($)	Aug. 07, 2013		Aug. 01, 2013	May. 10, 2013USD ($)	May. 06, 2013USD ($)	Apr. 30, 2013	Feb. 12, 2013USD ($)	Jan. 31, 2013	Sep. 30, 2015USD ($)shares	Dec. 31, 2014USD ($)shares	Oct. 31, 2013USD ($)	Jan. 31, 2013USD ($)	Mar. 31, 2016USD ($)shares	Mar. 31, 2015USD ($)shares	Sep. 30, 2015USD ($)shares	Dec. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)$ / sharesshares	Dec. 31, 2013USD ($)shares	Nov. 08, 2013USD ($)
Distribution Made to Limited Partner [Line Items]
Conversion ratio																											1.07											2.75						2.75
Distribution Made to Limited Partner, Unit Distribution | shares																																													1,271,935	387,991
Contribution from issuance of units																																															$ 714,000,000
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units																																													$ 58,800,000	$ 430,500,000
Preferred units, outstanding | shares																																						21,580,244	17,917,870					21,580,244	0	17,917,870
Preferred units, issued | shares																																							17,917,870						0	17,917,870
Distributions to partners																																										$ (101,000,000)	$ (111,400,000)		$ (819,500,000)	$ (470,500,000)	(419,700,000)
Distribution Made to Limited Partner, Date of Record								Aug. 7, 2015		May 8, 2015		Feb. 6, 2015			Nov. 7, 2014		Aug. 7, 2014			May 8, 2014		Feb. 7, 2014			Nov. 7, 2013	[1]				Aug. 7, 2013	[1]	Aug. 1, 2013			Apr. 30, 2013		Jan. 31, 2013
Distribution Made to Limited Partner, Distribution Date						Aug. 14, 2015			May 15, 2015		Feb. 13, 2015			Nov. 14, 2014		Aug. 14, 2014			May 15, 2014		Feb. 14, 2014		Nov. 14, 2013					Aug. 14, 2013	Aug. 9, 2013				May 10, 2013			Feb. 12, 2013
Dividends, Paid-in-kind		$ 12,800,000																																								13,100,000	10,400,000		$ 31,900,000	9,700,000
Incentive Distribution, Distribution Per Unit | $ / shares																																													$ 0.30
Distribution Made to General Partner, Cash Distributions Paid																																													$ 31,400,000	41,800,000	26,200,000
Net Distribution Paid To Limited Partner																																													175,600,000	101,600,000	50,000,000
Distribution Made to Limited Partner, Cash Distributions Paid						$ 74,300,000			$ 74,300,000		$ 74,300,000			$ 74,100,000		$ 74,100,000			$ 74,200,000		$ 74,100,000		$ 69,500,000					$ 34,300,000	$ 27,400,000				$ 27,400,000			$ 21,000,000						97,200,000	26,600,000		222,900,000	296,500,000	179,600,000
Investment in unconsolidated affiliates in period																																										5,500,000	17,900,000		41,800,000	144,400,000	151,500,000
Issuance of preferred equity of subsidiary																																														53,900,000	96,100,000
Distribution made to limited partners																																										0	$ 0		0	0	$ (5,500,000)
Cash																											$ 34,900,000													$ 34,900,000
Consideration transferred																																									$ 258,000,000
Percentage of voting interests acquired																																															65.00%
Preferred Stock Dividends, Shares | shares		1,404,317																																									414,325
Limited Partners' Capital Account, Distribution Amount																																											$ 10,500,000
Legacy Crestwood Credit Facility [Member]
Distribution Made to Limited Partner [Line Items]
Consideration transferred																																									$ 129,000,000
Non-Controlling Partners
Distribution Made to Limited Partner [Line Items]
Contribution from issuance of units																																															$ 0
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units																																													$ 0	0
Issuance of preferred equity of subsidiary																																														53,900,000	96,100,000
Partners' Capital Account, Acquisitions																																															(182,300,000)
Limited Partner
Distribution Made to Limited Partner [Line Items]
Partners' Capital Account, Acquisitions																																															$ 182,300,000
Subsequent Event
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Date of Record	May 6, 2016
Distribution Made to Limited Partner, Distribution Date	May 13, 2016
Preferred Stock Dividends, Shares | shares	1,436,797
Crestwood Holdings | Majority Shareholder
Distribution Made to Limited Partner [Line Items]
Shares exchanged by acquirer | shares																											7,100,000
Cash Distribution
Distribution Made to Limited Partner [Line Items]
Limited Partners' Capital Account, Distribution Amount																																											74,300,000
Cash Distribution | Subsequent Event
Distribution Made to Limited Partner [Line Items]
Distribution declared per limited partner unit | $ / shares	$ 0.60
Tres Palacios Holdings LLC
Distribution Made to Limited Partner [Line Items]
Distribution Made to General Partner, Cash Distributions Paid																																														30,600,000
Investment in unconsolidated affiliates in period																																							$ 66,400,000			$ 5,500,000	5,700,000
Equity method ownership percentage																																										50.01%			50.01%
Cash																																							132,800,000
Jackalope Gas Gathering Services, L.L.C.
Distribution Made to Limited Partner [Line Items]
Investment in unconsolidated affiliates in period																																							$ 107,500,000
Equity method ownership percentage																																										50.00%			50.00%
Crestwood Niobrara LLC | Cash Distribution
Distribution Made to Limited Partner [Line Items]
Distribution made to limited partners																																													$ 11,300,000
Preferred Partner [Member]
Distribution Made to Limited Partner [Line Items]
Partners' Capital Account, Private Placement of Units, Price Per Unit | $ / shares																																													$ 25.10
Partners' Capital, Distribution Amount Per Share | $ / shares																																													0.5804
Limited Partner | Subordinated Unit
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Unit Distribution | 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
Legacy Crestwood [Member]
Distribution Made to Limited Partner [Line Items]
Incentive Distribution, Distribution																																															$ 9,300,000
CMLP
Distribution Made to Limited Partner [Line Items]
Distributions to partners																																															(11,800,000)
Arrow Midstream Holdings, LLC
Distribution Made to Limited Partner [Line Items]
Contribution from issuance of units																																															200,000,000
Cash																																								550,000,000
Consideration transferred																																																$ 750,000,000
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares | shares																								8,826,125
Arrow Midstream Holdings, LLC | Non-Controlling Partners
Distribution Made to Limited Partner [Line Items]
Contribution from issuance of units																																															$ 0
Preferred Units, Class C
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Unit Distribution | shares																																															183,995
Preferred Units, Class D
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Unit Distribution | shares																																															292,660
Preferred Units, Class A
Distribution Made to Limited Partner [Line Items]
Contribution from issuance of units																																														$ 17,529,879
Partners' Capital Account, Private Placement of Units, Price Per Unit | $ / shares																		$ 25.10																												$ 25,100
Proceeds from Issuance of Preferred Limited Partners Units, Gross							$ 60,000,000																																							$ 440,000,000
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units							$ 58,800,000																																							$ 430,500,000
Preferred Units, Class A | Maximum | Class A Purchasers
Distribution Made to Limited Partner [Line Items]
Contribution from issuance of units																		$ 500,000,000
Preferred Units | Jackalope Gas Gathering Services, L.L.C.
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Unit Distribution | shares													3,680,570																																	11,419,241	2,161,657
Crestwood Equity Partners LP
Distribution Made to Limited Partner [Line Items]
Incentive Distribution Rights, Ownership Percentage																																										100.00%		100.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest																																												99.90%	99.90%
Distribution Made to Limited Partner, Unit Distribution | shares		1,404,317																																											1,372,573
Contribution from issuance of units																																															$ 714,000,000
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units																																													$ (58,800,000)	$ (430,500,000)
Preferred units, outstanding | shares																																							0			62,122,562			60,718,245	0
Preferred units, issued | shares																																						59,345,672	0			62,122,562		59,345,672	60,718,245	0
Maximum Period For Distribution Of Available Cash																																													45 days
Distributions to partners																																										$ (95,600,000)	(25,800,000)		$ (171,500,000)	$ (102,500,000)	(68,400,000)
Distribution Made to Limited Partner, Date of Record			Feb. 5, 2016		Nov. 6, 2015			Aug. 7, 2015		May 8, 2015		Feb. 6, 2015			Nov. 7, 2014		Aug. 7, 2015			May 8, 2014		Feb. 7, 2014			Nov. 7, 2013					Aug. 7, 2013
Distribution Made to Limited Partner, Distribution Date		Feb. 12, 2016		Nov. 13, 2015		Aug. 14, 2015			May 15, 2015		Feb. 13, 2015			Nov. 14, 2014		Aug. 14, 2014			May 15, 2014		Feb. 14, 2014		Nov. 14, 2013					Aug. 14, 2013
Dividends, Paid-in-kind		$ 12,800,000																																											12,500,000
Distribution Made to Limited Partner, Cash Distributions Paid		$ 95,600,000		$ 94,300,000		$ 25,700,000			$ 25,700,000		$ 25,800,000			$ 25,600,000		$ 25,600,000			$ 25,700,000		$ 25,600,000		$ 25,000,000					$ 22,300,000										$ 378,300,000						$ 378,300,000	171,500,000	102,500,000	47,300,000
Investment in unconsolidated affiliates in period																																										5,500,000	18,100,000		42,000,000	108,600,000	151,500,000
Issuance of preferred equity of subsidiary																																														53,900,000	96,100,000
Distribution made to limited partners																																										$ 3,800,000	74,300,000		234,200,000	296,500,000	204,500,000
Preferred Stock Dividends, Shares | shares																																										1,400,000
Crestwood Equity Partners LP | Non-Controlling Partners
Distribution Made to Limited Partner [Line Items]
Contribution from issuance of units																																															714,000,000
Net proceeds from the issuance of Crestwood Midstream Partners LP Class A preferred units																																													$ (58,800,000)	(430,500,000)
Issuance of preferred equity of subsidiary																																														53,900,000	96,100,000
Partners' Capital Account, Acquisitions																																															(182,300,000)
Crestwood Equity Partners LP | Crestwood Holdings
Distribution Made to Limited Partner [Line Items]
Shares issued by acquiree | shares																											14,300,000
Crestwood Equity Partners LP | Cash Distribution
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Date of Record			Feb. 5, 2016
Distribution Made to Limited Partner, Distribution Date		Feb. 12, 2016
Distribution declared per limited partner unit | $ / shares		$ 1.3750
Crestwood Equity Partners LP | Preferred Partner [Member]
Distribution Made to Limited Partner [Line Items]
Partners' Capital, Contingent Distribution Amount Per Share | $ / shares																																													$ 0.2111
Partners' Capital, Distribution Amount Per Share | $ / shares																																													$ 0.2567
Partner's Capital, Unpaid Distribution, Accrual Percentage																																													2.8125%
Crestwood Equity Partners LP | Arrow Midstream Holdings, LLC
Distribution Made to Limited Partner [Line Items]
Contribution from issuance of units																																															200,000,000
Crestwood Equity Partners LP | Arrow Midstream Holdings, LLC | Non-Controlling Partners
Distribution Made to Limited Partner [Line Items]
Contribution from issuance of units																																															200,000,000
Crestwood Equity Partners LP | Preferred Units, Class A
Distribution Made to Limited Partner [Line Items]
Partners' Capital Account, Private Placement of Units, Price Per Unit | $ / shares																																													$ 9.13
Crestwood Equity Partners LP | Restricted units
Distribution Made to Limited Partner [Line Items]
Distributions to partners																																															$ (11,800,000)
Crestwood Gas Services GP, LLC [Member]
Distribution Made to Limited Partner [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest																																												0.10%	0.10%
Crestwood Niobrara LLC
Distribution Made to Limited Partner [Line Items]
Issuance of preferred equity of subsidiary																																														150,000,000
Distribution made to limited partners																																										$ 3,800,000
Crestwood Niobrara LLC | Tres Palacios Holdings LLC
Distribution Made to Limited Partner [Line Items]
Investment in unconsolidated affiliates in period																																													$ 5,700,000
Crestwood Niobrara LLC | Jackalope Gas Gathering Services, L.L.C.
Distribution Made to Limited Partner [Line Items]
Investment in unconsolidated affiliates in period																																											$ 8,800,000		$ 25,400,000	$ 105,200,000
Crestwood Niobrara LLC | Preferred Units
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Unit Distribution | shares																																										3,680,570
Crestwood Holdings
Distribution Made to Limited Partner [Line Items]
Cash																																								$ 10,000,000
Cash payments to unitholders upon completion of merger																																		$ 10,000,000
[1]	Represents distributions associated with Inergy Midstream limited partner units.

Partners' Capital (Schedule of

Partners' Capital (Schedule of Issuance of Units) (Detail) - USD ($) $ / shares in Units, $ in Millions	Oct. 23, 2013	Sep. 13, 2013	Mar. 22, 2013	Oct. 30, 2013	Oct. 07, 2013	Apr. 30, 2013
Distributions Made to Members or Limited Partners [Abstract]
Units	16,100,000	11,773,191	5,175,000	2,100,000	773,191	675,000
Per Unit Gross Price		$ 22.50	$ 23.90
Per Unit Net Price	$ 21.19	$ 21.69	$ 23
Net Proceeds	$ 340.3	$ 255.2	$ 118.5

Partners' Capital (Schedule o71

Partners' Capital (Schedule of Partners' Capital Account, Distriubtions) (Detail) - USD ($) $ / shares in Units, $ in Millions	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	Nov. 14, 2014	Nov. 07, 2014	Aug. 14, 2014	Aug. 07, 2014	May. 15, 2014	May. 08, 2014	Feb. 14, 2014	Feb. 07, 2014	Nov. 14, 2013	Nov. 07, 2013		Aug. 14, 2013	Aug. 09, 2013	Aug. 07, 2013		Aug. 01, 2013	May. 10, 2013	Apr. 30, 2013	Feb. 12, 2013	Jan. 31, 2013	Sep. 30, 2015	Mar. 31, 2016	Mar. 31, 2015	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Disclosure Partners Capital Summary Of Quarterly Distributions Of Available Cash [Abstract]
Distribution to limited partner, record date						Aug. 7, 2015		May 8, 2015		Feb. 6, 2015		Nov. 7, 2014		Aug. 7, 2014		May 8, 2014		Feb. 7, 2014		Nov. 7, 2013	[1]			Aug. 7, 2013	[1]	Aug. 1, 2013		Apr. 30, 2013		Jan. 31, 2013
Distribution to limited partner, distribution date					Aug. 14, 2015		May 15, 2015		Feb. 13, 2015		Nov. 14, 2014		Aug. 14, 2014		May 15, 2014		Feb. 14, 2014		Nov. 14, 2013			Aug. 14, 2013	Aug. 9, 2013				May 10, 2013		Feb. 12, 2013
Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit					$ 0.410		$ 0.410		$ 0.41		$ 0.410		$ 0.410		$ 0.410		$ 0.410		$ 0.405			$ 0.400	$ 0.510				$ 0.510		$ 0.510
Distribution amount					$ 74.3		$ 74.3		$ 74.3		$ 74.1		$ 74.1		$ 74.2		$ 74.1		$ 69.5			$ 34.3	$ 27.4				$ 27.4		$ 21			$ 97.2	$ 26.6		$ 222.9	$ 296.5	$ 179.6
Distribution Made to Limited Partner, Date of Record						Aug. 7, 2015		May 8, 2015		Feb. 6, 2015		Nov. 7, 2014		Aug. 7, 2014		May 8, 2014		Feb. 7, 2014		Nov. 7, 2013	[1]			Aug. 7, 2013	[1]	Aug. 1, 2013		Apr. 30, 2013		Jan. 31, 2013
Distribution Made to Limited Partner, Distribution Date					Aug. 14, 2015		May 15, 2015		Feb. 13, 2015		Nov. 14, 2014		Aug. 14, 2014		May 15, 2014		Feb. 14, 2014		Nov. 14, 2013			Aug. 14, 2013	Aug. 9, 2013				May 10, 2013		Feb. 12, 2013
Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit					$ 0.410		$ 0.410		$ 0.41		$ 0.410		$ 0.410		$ 0.410		$ 0.410		$ 0.405			$ 0.400	$ 0.510				$ 0.510		$ 0.510
Distribution Made to Limited Partner, Cash Distributions Paid					$ 74.3		$ 74.3		$ 74.3		$ 74.1		$ 74.1		$ 74.2		$ 74.1		$ 69.5			$ 34.3	$ 27.4				$ 27.4		$ 21			$ 97.2	$ 26.6		222.9	296.5	179.6
Crestwood Equity Partners LP
Disclosure Partners Capital Summary Of Quarterly Distributions Of Available Cash [Abstract]
Distribution to limited partner, record date		Feb. 5, 2016		Nov. 6, 2015		Aug. 7, 2015		May 8, 2015		Feb. 6, 2015		Nov. 7, 2014		Aug. 7, 2015		May 8, 2014		Feb. 7, 2014		Nov. 7, 2013				Aug. 7, 2013
Distribution to limited partner, distribution date	Feb. 12, 2016		Nov. 13, 2015		Aug. 14, 2015		May 15, 2015		Feb. 13, 2015		Nov. 14, 2014		Aug. 14, 2014		May 15, 2014		Feb. 14, 2014		Nov. 14, 2013			Aug. 14, 2013
Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit	$ 1.375		$ 1.375		$ 1.375		$ 1.375		$ 1.375		$ 1.375		$ 1.375		$ 1.375		$ 1.375		$ 1.350			$ 1.300
Distribution amount	$ 95.6		$ 94.3		$ 25.7		$ 25.7		$ 25.8		$ 25.6		$ 25.6		$ 25.7		$ 25.6		$ 25			$ 22.3									$ 378.3			$ 378.3	171.5	102.5	47.3
Distribution Made to Limited Partner, Date of Record		Feb. 5, 2016		Nov. 6, 2015		Aug. 7, 2015		May 8, 2015		Feb. 6, 2015		Nov. 7, 2014		Aug. 7, 2015		May 8, 2014		Feb. 7, 2014		Nov. 7, 2013				Aug. 7, 2013
Distribution Made to Limited Partner, Distribution Date	Feb. 12, 2016		Nov. 13, 2015		Aug. 14, 2015		May 15, 2015		Feb. 13, 2015		Nov. 14, 2014		Aug. 14, 2014		May 15, 2014		Feb. 14, 2014		Nov. 14, 2013			Aug. 14, 2013
Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit	$ 1.375		$ 1.375		$ 1.375		$ 1.375		$ 1.375		$ 1.375		$ 1.375		$ 1.375		$ 1.375		$ 1.350			$ 1.300
Distribution Made to Limited Partner, Cash Distributions Paid	$ 95.6		$ 94.3		$ 25.7		$ 25.7		$ 25.8		$ 25.6		$ 25.6		$ 25.7		$ 25.6		$ 25			$ 22.3									$ 378.3			$ 378.3	$ 171.5	$ 102.5	$ 47.3
[1]	Represents distributions associated with Inergy Midstream limited partner units.

Partners' Capital Schedule of C

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

Aug. 14, 2015

Aug. 07, 2015

May. 15, 2015

May. 08, 2015

Feb. 13, 2015

Feb. 06, 2015

Nov. 14, 2014

Nov. 07, 2014

Aug. 14, 2014

Aug. 07, 2014

May. 15, 2014

May. 08, 2014

Feb. 14, 2014

Feb. 07, 2014

Nov. 14, 2013

Nov. 07, 2013

[1]

Aug. 14, 2013

Aug. 09, 2013

Aug. 07, 2013

[1]

Aug. 01, 2013

May. 10, 2013

Apr. 30, 2013

Feb. 12, 2013

Jan. 31, 2013

Mar. 31, 2016

Mar. 31, 2015

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Distributions Made to Members or Limited Partners [Abstract]

Distribution to limited partner, record date

Aug. 7, 2015

May 8, 2015

Feb. 6, 2015

Nov. 7, 2014

Aug. 7, 2014

May 8, 2014

Feb. 7, 2014

Nov. 7, 2013

Aug. 7, 2013

Aug. 1, 2013

Apr. 30, 2013

Jan. 31, 2013

Distribution to limited partner, distribution date

Aug. 14, 2015

May 15, 2015

Feb. 13, 2015

Nov. 14, 2014

Aug. 14, 2014

May 15, 2014

Feb. 14, 2014

Nov. 14, 2013

Aug. 14, 2013

Aug. 9, 2013

May 10, 2013

Feb. 12, 2013

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.410

$ 0.410

$ 0.41

$ 0.410

$ 0.410

$ 0.410

$ 0.410

$ 0.405

$ 0.400

$ 0.510

$ 0.510

$ 0.510

Distribution Made to Limited Partner, Cash Distributions Paid

$ 74.3

$ 74.3

$ 74.3

$ 74.1

$ 74.1

$ 74.2

$ 74.1

$ 69.5

$ 34.3

$ 27.4

$ 27.4

$ 21

$ 97.2

$ 26.6

$ 222.9

$ 296.5

$ 179.6

[1]

Represents distributions associated with Inergy Midstream limited partner units.

Partners' Capital Net Income (L

Partners' Capital Net Income (Loss) Attributable to NonControlling Partners (Detail) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Limited Partners' Capital Account [Line Items]
Net income attributable to non-controlling partners in subsidiary	$ 5.9	$ 5.6	$ 23.1	$ 16.8	$ 4.9
Limited Partner
Limited Partners' Capital Account [Line Items]
Net income attributable to non-controlling partners in subsidiary			(683)	(100.8)	(62.2)
Preferred Units, Class A
Limited Partners' Capital Account [Line Items]
Net income attributable to non-controlling partners in subsidiary	0	9.2	23.1	17.2	0
Crestwood Niobrara LLC
Limited Partners' Capital Account [Line Items]
Net income attributable to non-controlling partners in subsidiary	5.9	5.6	23.1	16.8	4.9
Crestwood Equity Partners LP
Limited Partners' Capital Account [Line Items]
Net income attributable to non-controlling partners in subsidiary	$ 5.9	$ 9.8	$ (636.8)	$ (66.8)	$ (57.3)

Equity Plans (Detail)

Equity Plans (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Feb. 12, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 11.5	$ 10.1	$ 10.9
Employer matching contribution, percent	6.00%
Crestwood Midstream Long-Term Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Conversion ratio	2.75
Compensation expense	$ 8.1	$ 11.2	11.4
Common units to satisfy employee tax withholding obligations	139,331	71,484
Crestwood Midstream Long-Term Incentive Plan | Restricted units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation costs not yet recognized	$ 16.5	$ 8.1
Shares reserved for future issuance				5,978,939
Crestwood Midstream Long-Term Incentive Plan | Restricted units | CMLP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation costs not yet recognized		$ 9.5
Crestwood Long-Term Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common units to satisfy employee tax withholding obligations	26,095	15,944
Legacy Crestwood Long-Term Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense			$ 6.5
Employee Unit Purchase Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum annual contributions per employee, percent	10.00%
Employer matching contribution, percent	10.00%
Maximum purchasable units	200,000

Equity Plans (Schedule of Phant

Equity Plans (Schedule of Phantom and Restricted Unit Activity) (Detail) - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
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	131,588	49,354
Unvested units - December 31	$ 132.1	$ 139.6
Vested, units	(91,798)	(44,993)
Vested	$ 121.13	$ 139.7
Granted, units	142,255	137,746
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
Granted	$ 55.25	$ 132.3
Canceled, units	(20,994)	(10,519)
Canceled	$ 89.97	$ 137.3
Unvested units - December 31, units	466,214	131,588
Unvested units - December 31	$ 69.8	$ 132.1
Crestwood Long-Term Incentive Plan | Restricted units | Employee Severance
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Canceled, units	(7,263)
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	$ 67.1
Granted, units	42,349
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
Granted	$ 62.31
Crestwood Midstream 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	834,796	250,557
Unvested units - December 31	$ 23.18	$ 22.13
Vested, units	(457,458)	(208,361)
Vested	$ 22.91	$ 22.15
Granted, units	535,858	871,078
Share-based Compensation Arrangement by Share-based Payment Award, Other Share Increase (Decrease)	(823,277)
Share Based Compensation Arrangement By Share Based Payment Award Other Shares Increase Decrease Weighted Average Grant Date Fair Value	$ 20.06
Granted	$ 15.89	$ 23.25
Canceled, units	(89,919)	(78,478)
Canceled	$ 16.05	$ 23.33
Unvested units - December 31, units	0	834,796
Unvested units - December 31	$ 0	$ 23.18
Crestwood Midstream Long-Term Incentive Plan | Restricted units | Employee Severance
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Canceled, units	(39,172)
Crestwood Midstream 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	(21,578)
Vested	$ 16.05
Granted, units	171,648
Share-based Compensation Arrangement by Share-based Payment Award, Other Share Increase (Decrease)	(150,070)
Share Based Compensation Arrangement By Share Based Payment Award Other Shares Increase Decrease Weighted Average Grant Date Fair Value	$ 18.93
Granted	$ 15.76

Employee Benefit Plan (Detail)

Employee Benefit Plan (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Postemployment Benefits [Abstract]
Defined Contribution Plan, Employer Matching Contribution, Percent	90.00%
Defined Benefit Plan, Employee Contributions, Statutory Maximum Per Employee	$ 18,000	$ 17,500	$ 17,500
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, Contributions by Employer	$ 4,000,000	$ 3,800,000	$ 500,000

Commitments and Contingencies77

Commitments and Contingencies (Detail) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Feb. 28, 2015USD ($)	Dec. 31, 2014USD ($)	Nov. 08, 2013bblPerson
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Estimate of Possible Loss	$ 7	$ 7
Payments for Other Taxes	8.6	8.6
Loss Contingency Accrual, at Carrying Value		0.1		$ 1
Self Insurance Reserve	12.3	11.4		7.2
Self Insurance Reserve Expected To Be Paid Subsequent To Next Fiscal Year	7.1	7.1
Commodity
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Firm Purchase Commitments		188.3
Antero
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Contingent consideration, current liability			$ 40	40
Arrow Acquisition Class Action Lawsuit
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Loss of Life, Number | Person					47
Arrow Acquisition Class Action Lawsuit | Minimum
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Barrels of Oil Equivalents Spilled | bbl					50,000
Identified Growth Projects
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Firm Purchase Commitments		12.7
Other Growth and Maintenance Contractual Purchase Obligations
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Firm Purchase Commitments		13.5
Tres Palacios Holdings LLC
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Estimate of Possible Loss	2	2
Crestwood Equity Partners LP
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Self Insurance Reserve	17.8	17.2		$ 14.6
Self Insurance Reserve Expected To Be Paid Subsequent To Next Fiscal Year	$ 11.3	$ 11.3

Commitments and Contingencies E

Commitments and Contingencies Environmental Compliance (Detail) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)bblRelease	Dec. 31, 2014USD ($)Release	Sep. 15, 2015USD ($)	May. 06, 2015bbl
Site Contingency [Line Items]
Loss Contingency, Range of Possible Loss, Maximum				$ 1.1
Fort Berthold Indian Reservation
Site Contingency [Line Items]
Site Contingency, Loss Exposure, Number of Releases of Produced Water | Release		3	3
Site Contingency, Loss Exposure, Release of Produced Water | bbl		28,000			5,200
Accrual for Environmental Loss Contingencies	$ 1.7	$ 1.7	$ 1.1
Site Contingency, Loss Exposure in Excess of Accrual, Low Estimate	1.7	1.7
Site Contingency, Loss Exposure in Excess of Accrual, High Estimate	$ 3.5	$ 3.7

Commitments and Contingencies79

Commitments and Contingencies (Schedule of Future Minimum Lease Payments under Noncancelable Operatng Leases) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]
2,016	$ 19.1
2,017	16.6
2,018	15.3
2,019	14.1
2,020	9.2
Thereafter	23.8
Operating Leases, Future Minimum Payments Due	98.1
Rent expense	$ 37.4	$ 41.8	$ 16.4

Related Party Transactions (Det

Related Party Transactions (Detail) $ in Millions	3 Months Ended		9 Months Ended	12 Months Ended
	Mar. 31, 2016USD ($)	Mar. 31, 2015USD ($)	Sep. 30, 2015USD ($)Person	Dec. 31, 2015USD ($)Person	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Related Party Transaction [Line Items]
Entity Number of Employees | people | Person			100
Related Party Costs			$ 0.8
Gathering and processing revenues at CEQP and CMLP	$ 0.7	$ 1		$ 3.9	$ 3	$ 74.9
General and administrative expenses charged by CEQP to Crestwood Holdings, net(3)	0.7	0.9		2.8	0.2	0
General and administrative expenses charged by CEQP to CMLP, net(2)	3.7	17.4		49.5	63.6	34.7
Affiliated Entity
Related Party Transaction [Line Items]
Gathering and processing costs of product/services sold at CEQP and CMLP(1)	4.3	8.3		28.9	42.2	32.5
General and administrative expenses charged by CEQP to CMLP, net(2)	0.8
Accounts receivable	1.1			1.7	0.3
Related Party Transaction, Due from (to) Related Party [Abstract]
Accounts payable	1.3			1.5	3.1
Crestwood Long-Term Incentive Plan
Related Party Transaction [Line Items]
Allocated share based compensation expense	4.5	2.2		10	6.9	4.4
Crestwood Equity Partners LP
Related Party Transaction [Line Items]
Gathering and processing revenues at CEQP and CMLP	0.7	1		3.9	3	74.9
General and administrative expenses charged by CEQP to Crestwood Holdings, net(3)	0.1	$ 0.1		0.4	0.5	$ 25.3
Crestwood Equity Partners LP | Affiliated Entity
Related Party Transaction [Line Items]
Accounts receivable	1.1			1.7	0.6
Related Party Transaction, Due from (to) Related Party [Abstract]
Accounts payable	3.8			$ 4	$ 5.6
Crestwood Operations LLC
Related Party Transaction [Line Items]
Entity Number of Employees | people | Person				1,288
General And Administrative Employees | people | Person				297
Operational Employees | people | Person				991
Crestwood Holdings | Crestwood Long-Term Incentive Plan
Related Party Transaction [Line Items]
Allocated share based compensation expense	$ 0.1			$ 0.1

Segments (Reconciliation of Net

Segments (Reconciliation of Net Income (Loss) to EBITDA) (Detail) $ in Millions	3 Months Ended									12 Months Ended
	Mar. 31, 2016USD ($)Segment	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Sep. 30, 2014USD ($)	Jun. 30, 2014USD ($)	Mar. 31, 2014USD ($)	Dec. 31, 2015USD ($)Segment	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Segment Reporting, Other Significant Reconciling Item [Line Items]
Number of operating segments | Segment	3									3
Net income (loss)	$ (95.3)	$ (756.7)	$ (610.2)	$ (72.8)	$ 29.1	$ (49.2)	$ 27.1	$ 11	$ 25.8	$ (1,410.6)	$ 14.7	$ (12.4)
Interest and debt expense, net	36.1				29.9					130.5	111.4	71.7
Loss on modification/extinguishment of debt										18.9	0	0
Provision (benefit) for income taxes	(0.2)				0.4					0	0.9	0.7
Depreciation, amortization and accretion	64.9				68.8					278.5	255.4	139.4
EBITDA	5.5				128.2					(982.7)	382.4	199.4
Crestwood Equity Partners LP
Segment Reporting, Other Significant Reconciling Item [Line Items]
Net income (loss)	(93.7)	$ (1,402.4)	$ (623.4)	$ (296)	18.1	$ (30.7)	$ 11.9	$ (4.8)	$ 13.2	(2,303.7)	(10.4)	(50.6)
Interest and debt expense, net	36.1				33.6					140.1	127.1	77.9
Loss on modification/extinguishment of debt										20	0	0
Provision (benefit) for income taxes	0				0.4					(1.4)	1.1	1
Depreciation, amortization and accretion	62.3				74.2					300.1	285.3	167.9
EBITDA	$ 4.7				$ 126.3					$ (1,844.9)	$ 403.1	$ 196.2

Segments (Narrative) (Detail)

Segments (Narrative) (Detail) - USD ($) $ in Millions	3 Months Ended									12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Interest, Taxes, Depreciation and Amortization included in Earnings from Equity Method Investments	$ 2.6				$ 3.1					$ 86.1	$ 7.6	$ 2.6
Concentration Risk, Percentage										10.00%
Revenues	536	$ 629.1	$ 630.7	$ 641.5	731.5	$ 994.9	$ 1,033.8	$ 923.9	$ 964.9	$ 2,632.8	3,917.5	1,412.6
Tesoro
Segment Reporting Information [Line Items]
Revenues										465.2
Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
Interest, Taxes, Depreciation and Amortization included in Earnings from Equity Method Investments	2.6				3.1					86.1	7.6	2.6
Revenues	$ 536	$ 629.1	$ 630.7	$ 641.5	$ 731.5	$ 997.2	$ 1,036.2	$ 926.3	$ 971.6	$ 2,632.8	$ 3,931.3	$ 1,426.7

Segments (Summary Of Segment In

Segments (Summary Of Segment Information) (Detail) - USD ($) $ in Millions	3 Months Ended									12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Jun. 19, 2013
Segment Reporting Information [Line Items]
Operating revenues	$ 536	$ 629.1	$ 630.7	$ 641.5	$ 731.5	$ 994.9	$ 1,033.8	$ 923.9	$ 964.9	$ 2,632.8	$ 3,917.5	$ 1,412.6
Intersegment Revenues	0				0					0	0
Costs of product/services sold	363.4				529.7					1,883.5	3,154.8	995.4
Operations and maintenance	41.7				50.6					188.7	195.4	103.4
General and administrative	22.2				25.6					105.6	91.7	84.1
Gain (loss) on long-lived assets, net	0				(0.8)					227.8	35.1	(5.3)
Goodwill impairment	(109.7)	(470.6)			0					(1,149.1)	(48.8)	(4.1)
Loss on contingent consideration (Note 15)										0	(8.6)	(31.4)
Earnings from unconsolidated affiliates, net	6.5	(72)	2.8	5	3.4	0.6	0.3	(1.5)	(0.1)	(60.8)	(0.7)	(0.1)
EBITDA	5.5				128.2					(982.7)	382.4	199.4
Goodwill	975.8	1,085.5				2,234.6				1,085.5	2,234.6	2,295.1	$ 1,532.7
Assets	5,767.4	5,963.6				7,785.2				5,963.6	7,785.2
Payments to Acquire Property, Plant, and Equipment	55.6				47.4					182.7	421.7	339.3
Scenario, Previously Reported
Segment Reporting Information [Line Items]
Assets		6,004.5								6,004.5
Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
Operating revenues	536	629.1	630.7	641.5	731.5	997.2	1,036.2	926.3	971.6	2,632.8	3,931.3	1,426.7
Intersegment Revenues	0				0					0	0
Costs of product/services sold	363.4				529.7					1,883.5	3,165.3	1,002.3
Operations and maintenance	41.8				50.6					190.2	203.3	104.6
General and administrative	23				27.5					116.3	100.2	93.5
Gain (loss) on long-lived assets, net	0				(1)					821.2	1.9	(5.3)
Goodwill impairment	(109.7)	(515.4)			0					(1,406.3)	(48.8)	(4.1)
Loss on contingent consideration (Note 15)											(8.6)	(31.4)
Earnings from unconsolidated affiliates, net	6.5	(72)	$ 2.8	$ 5	3.4	0.6	$ 0.3	$ (1.5)	$ (0.1)	(60.8)	(0.7)	(0.1)
Other income, net	0.1				0.2					0.6	0.6	0.2
EBITDA	4.7				126.3					(1,844.9)	403.1	196.2
Goodwill	975.8	1,085.5				2,491.8				1,085.5	2,491.8	2,552.3	$ 2,134.8
Assets	5,570	5,762.8				8,461.4				5,762.8	8,461.4
Payments to Acquire Property, Plant, and Equipment	55.6				47.4					182.7	424	347
Crestwood Equity Partners LP | Scenario, Previously Reported
Segment Reporting Information [Line Items]
Assets		5,803.7								5,803.7
Gathering systems and pipelines
Segment Reporting Information [Line Items]
Operating revenues										1,381	2,166.8	510
Intersegment Revenues										66.7	50
Costs of product/services sold										1,103.9	1,859.9	267.5
Operations and maintenance										89	102.8	58.7
General and administrative										0	0	0
Gain (loss) on long-lived assets, net										194.1	32.7	(5.4)
Goodwill impairment										(72.5)	(18.5)	(4.1)
Loss on contingent consideration (Note 15)											(8.6)	(31.4)
Earnings from unconsolidated affiliates, net										(43.4)	0.5	0.1
EBITDA										(55.2)	194.8	153.8
Goodwill		54.5				127				54.5	127
Assets		2,541.6				2,941.6				2,541.6	2,941.6
Payments to Acquire Property, Plant, and Equipment										132.7	327.9	290.7
Gathering systems and pipelines | Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
Operating revenues										1,381	2,166.8
Intersegment Revenues										66.7	50
Costs of product/services sold										1,103.9	1,859.9
Operations and maintenance										89	102.8
General and administrative										0	0
Gain (loss) on long-lived assets, net										787.3	32.7
Goodwill impairment										(329.7)	(18.5)
Loss on contingent consideration (Note 15)											(8.6)
Earnings from unconsolidated affiliates, net										(43.4)	0.5
Other income, net										0	0
EBITDA										(905.6)	194.8
Goodwill		54.5				384.2				54.5	384.2
Assets		2,325.2				3,593.6				2,325.2	3,593.6
Payments to Acquire Property, Plant, and Equipment										132.7	327.9
Storage and Transportation
Segment Reporting Information [Line Items]
Operating revenues	59.4				67.6					266.3	250.8	116.8
Intersegment Revenues	0.4				0					0	0
Costs of product/services sold	2.9				5.3					20.1	22.8	12.8
Operations and maintenance	7.1				6.4					30.2	22.1	12.4
General and administrative	0				0					0	0	0
Gain (loss) on long-lived assets, net					(0.5)					1.4	(0.6)	0
Goodwill impairment	(13.7)									(623.4)	0	0
Loss on contingent consideration (Note 15)											0	0
Earnings from unconsolidated affiliates, net	1.4				0.9					(17.4)	(1.2)	(0.2)
EBITDA	37.5				56.3					(426.2)	205.3	91.4
Goodwill	757.5	771.2				1,394.6				771.2	1,394.6
Assets	2,185	2,216.7				2,423.3				2,216.7	2,423.3
Payments to Acquire Property, Plant, and Equipment	3.3				4.1					26.4	36.4	35.7
Storage and Transportation | Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
Operating revenues	59.4				67.6					266.3	264.6	130.9
Intersegment Revenues	0.4				0					0	0
Costs of product/services sold	2.9				5.3					20.1	33.3	19.7
Operations and maintenance	7.2				6.4					31.7	28.8	14.2
General and administrative	0				0					0	0	0
Gain (loss) on long-lived assets, net					(0.7)					1.6	(33.8)	0
Goodwill impairment	(13.7)									(623.4)	0	0
Loss on contingent consideration (Note 15)											0	0
Earnings from unconsolidated affiliates, net	1.4				0.9					(17.4)	(1.2)	(0.2)
Other income, net	0				0					0	0	0
EBITDA	37.4				56.1					(427.9)	235.1	96.8
Goodwill	757.5	771.2				1,394.6				771.2	1,394.6
Assets	2,185.7	2,217.4				2,423.3				2,217.4	2,423.3
Payments to Acquire Property, Plant, and Equipment	3.3				4.1					26.4	37	43.4
Marketing Supply and Logistics
Segment Reporting Information [Line Items]
Operating revenues	237.7				313.6					985.5	1,499.9	785.8
Intersegment Revenues	(20.9)				(10.1)					(66.7)	(50)
Costs of product/services sold	180.7				257.7					759.5	1,272.1	715.1
Operations and maintenance	16.8				20.1					69.5	70.5	32.3
General and administrative	0				0					0	0	0
Gain (loss) on long-lived assets, net					0					32.3	3	0.1
Goodwill impairment	(87.4)									(453.2)	(30.3)	0
Loss on contingent consideration (Note 15)											0	0
Earnings from unconsolidated affiliates, net	0				0					0	0	0
EBITDA	(68.1)				25.7					(395.7)	74	38.3
Goodwill	172.4	259.8				713				259.8	713
Assets	924.4	1,083.7				2,240.6				1,083.7	2,240.6
Payments to Acquire Property, Plant, and Equipment	7.1				6.9					22.8	50.9	11.9
Marketing Supply and Logistics | Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
Operating revenues	237.7				313.6					985.5	1,499.9	785.8
Intersegment Revenues	(20.9)				(10.1)					(66.7)	(50)
Costs of product/services sold	180.7				257.7					759.5	1,272.1	715.1
Operations and maintenance	16.8				20.1					69.5	71.7	31.7
General and administrative	0				0					0		0
Gain (loss) on long-lived assets, net					0					32.3	3	0.1
Goodwill impairment	(87.4)									(453.2)	(30.3)	0
Loss on contingent consideration (Note 15)											0	0
Earnings from unconsolidated affiliates, net	0				0					0	0	0
Other income, net	0				0					0	0	0
EBITDA	(68.1)				25.7					(395.7)	72.8	38.9
Goodwill	172.4	259.8				713				259.8	713
Assets	924.4	1,083.7				2,240.6				1,083.7	2,240.6
Payments to Acquire Property, Plant, and Equipment	7.1				6.9					22.8	50.9	11.9
Corporate
Segment Reporting Information [Line Items]
Operating revenues	0				0					0	0	0
Intersegment Revenues	0				0					0	0
Costs of product/services sold	0				0					0	0	0
Operations and maintenance	0				0					0	0	0
General and administrative	22.2				25.6					105.6	91.7	84.1
Gain (loss) on long-lived assets, net					0					0	0	0
Goodwill impairment	0									0	0	0
Loss on contingent consideration (Note 15)											0	0
Earnings from unconsolidated affiliates, net	0				0					0	0	0
EBITDA	(22.2)				(25.6)					(105.6)	(91.7)	(84.1)
Goodwill	0	0				0				0	0
Assets	123.9	162.5				179.7				162.5	179.7
Payments to Acquire Property, Plant, and Equipment	0.9				0.2					0.8	6.5	1
Corporate | Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
Operating revenues	0				0					0	0	0
Intersegment Revenues	0				0					0	0
Costs of product/services sold	0				0					0	0	0
Operations and maintenance	0				0					0	0	0
General and administrative	23				27.5					116.3	100.2	93.5
Gain (loss) on long-lived assets, net					0					0	0	0
Goodwill impairment	0									0	0	0
Loss on contingent consideration (Note 15)											0	0
Earnings from unconsolidated affiliates, net	0				0					0	0	0
Other income, net	0.1				0.2					0.6	0.6	0.2
EBITDA	(22.9)				(27.3)					(115.7)	(99.6)	(93.3)
Goodwill	0	0				0				0	0
Assets	138.7	$ 177.4				$ 203.9				177.4	203.9
Payments to Acquire Property, Plant, and Equipment	0.9				0.2					$ 0.8	$ 8.2	1
Gathering and Processing Operations
Segment Reporting Information [Line Items]
Operating revenues	238.9				350.3
Intersegment Revenues	20.5				10.1
Costs of product/services sold	179.8				266.7
Operations and maintenance	17.8				24.1
General and administrative	0				0
Gain (loss) on long-lived assets, net					(0.3)
Goodwill impairment	(8.6)
Earnings from unconsolidated affiliates, net	5.1				2.5
EBITDA	58.3				71.8
Goodwill	45.9
Assets	2,534.1
Payments to Acquire Property, Plant, and Equipment	44.3				36.2
Gathering and Processing Operations | Crestwood Equity Partners LP
Segment Reporting Information [Line Items]
Operating revenues	238.9				350.3							510
Intersegment Revenues	20.5				10.1
Costs of product/services sold	179.8				266.7							267.5
Operations and maintenance	17.8				24.1							58.7
General and administrative	0				0							0
Gain (loss) on long-lived assets, net					(0.3)							(5.4)
Goodwill impairment	(8.6)											(4.1)
Loss on contingent consideration (Note 15)												(31.4)
Earnings from unconsolidated affiliates, net	5.1				2.5							0.1
Other income, net	0				0							0
EBITDA	58.3				71.8							153.8
Goodwill	45.9
Assets	2,321.2
Payments to Acquire Property, Plant, and Equipment	$ 44.3				$ 36.2							$ 290.7

Condensed Consolidating Finan84

Condensed Consolidating Financial Information (Balance Sheet) (Detail) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current assets:
Cash	$ 0.8	$ 0.1	$ 67.4	$ 7.6	$ 5.1	$ 0.1
Accounts receivable	209.6	236.5		379.3
Inventory	26.6	44.5		46.6
Other current assets	33.3	52.5		103.1
Total current assets	270.3	333.6		536.6
Property, plant and equipment, net	3,514.4	3,525.7		3,746
Intangible assets		1,887.8		3,204.2
Goodwill and intangible assets, net	1,719.1	1,846.9
Investment in consolidated affiliates	0	0		0
Investment in unconsolidated affiliates	260.6	254.3	254.3	295.1
Other assets	3	3.1		3.3
Total assets	5,767.4	5,963.6		7,785.2
Current liabilities:
Accounts payable	116.5	141.4		235
Other current liabilities	102.8	111.6		176.3
Total current liabilities	219.3	253		411.3
Long-term liabilities:
Long-term debt, less current portion	2,530.8	2,501.8		2,014.5
Other long-term liabilities	44.1	43.3		38.3
Deferred income taxes	0.6	0.4		0.7
Partners' capital	2,787	2,981.6		5,148.7
Interest of non-controlling partners in subsidiaries	185.6	183.5		171.7
Total partners' capital	2,972.6	3,165.1		5,320.4	5,291.3	859.7
Total liabilities and partners' capital	5,767.4	5,963.6		7,785.2
Eliminations
Current assets:
Cash	0	0	0	0
Accounts receivable	0	0		0
Inventory	0	0		0
Other current assets	0	0
Total current assets	0	0		0
Property, plant and equipment, net	0	0		0
Intangible assets		0		0
Goodwill and intangible assets, net	0	0
Investment in consolidated affiliates	(5,350.2)	(5,506.8)		(7,148)
Investment in unconsolidated affiliates	0	0		0
Other assets	0	0		0
Total assets	(5,350.2)	(5,506.8)		(7,148)
Current liabilities:
Accounts payable	0	0		0
Other current liabilities	0	0		0
Total current liabilities	0	0		0
Long-term liabilities:
Long-term debt, less current portion	0	0		0
Other long-term liabilities	0	0		0
Deferred income taxes	0	0		0
Partners' capital	(5,350.2)	(5,506.8)		(7,148)
Interest of non-controlling partners in subsidiaries	0	0		0
Total partners' capital	(5,350.2)	(5,506.8)		(7,148)
Total liabilities and partners' capital	(5,350.2)	(5,506.8)		(7,148)
Scenario, Previously Reported
Current assets:
Total assets		6,004.5
Long-term liabilities:
Long-term debt, less current portion		2,542.7
Total liabilities and partners' capital		6,004.5
Parent Company
Current assets:
Cash	0.8	0.1	0	0	0.1
Accounts receivable	0	0		1.2
Inventory	0	0		0
Other current assets	0	0		0
Total current assets	0.8	0.1		1.2
Property, plant and equipment, net	0	0		7.9
Intangible assets		40.9		38
Goodwill and intangible assets, net	0	0
Investment in consolidated affiliates	5,350.2	5,506.8		7,148
Investment in unconsolidated affiliates	0	0		0
Other assets	0	0		0
Total assets	5,351	5,506.9		7,195.1
Current liabilities:
Accounts payable	0	0		9
Other current liabilities	35.8	26.4		23
Total current liabilities	35.8	26.4		32
Long-term liabilities:
Long-term debt, less current portion	2,528.2	2,498.9		2,012.8
Other long-term liabilities	0	0		1.6
Deferred income taxes	0	0		0
Partners' capital	2,787	2,981.6		5,148.7
Interest of non-controlling partners in subsidiaries	0	0		0
Total partners' capital	2,787	2,981.6		5,148.7
Total liabilities and partners' capital	5,351	5,506.9		7,195.1
Parent Company | Scenario, Previously Reported
Current assets:
Total assets		5,547.8
Long-term liabilities:
Long-term debt, less current portion		2,539.8
Total liabilities and partners' capital		5,547.8
Guarantor Subsidiaries
Current assets:
Cash	0	0	67.4	7.6	4	$ 0.1
Accounts receivable	209.1	236		377.8
Inventory	26.6	44.5		46.6
Other current assets	33.3	52.5		103.1
Total current assets	269	333		535.1
Property, plant and equipment, net	3,514.4	3,525.7		3,738.1
Intangible assets		1,846.9		3,166.2
Goodwill and intangible assets, net	1,719.1	1,846.9
Investment in consolidated affiliates	0	0		0
Investment in unconsolidated affiliates	0	0		0
Other assets	3	3.1		3.3
Total assets	5,505.5	5,708.7		7,442.7
Current liabilities:
Accounts payable	116.5	141.3		225.8
Other current liabilities	67	85.2		153.3
Total current liabilities	183.5	226.5		379.1
Long-term liabilities:
Long-term debt, less current portion	2.6	2.9		1.7
Other long-term liabilities	44.1	43.3		36.7
Deferred income taxes	0.6	0.4		0.7
Partners' capital	5,274.7	5,435.6		7,024.5
Interest of non-controlling partners in subsidiaries	0	0		0
Total partners' capital	5,274.7	5,435.6		7,024.5
Total liabilities and partners' capital	5,505.5	5,708.7		7,442.7
Non-Guarantor Subsidiaries
Current assets:
Cash	0	0	$ 0	0	$ 1
Accounts receivable	0.5	0.5		0.3
Inventory	0	0		0
Other current assets	0	0		0
Total current assets	0.5	0.5		0.3
Property, plant and equipment, net	0	0		0
Intangible assets		0		0
Goodwill and intangible assets, net	0	0
Investment in consolidated affiliates	0	0		0
Investment in unconsolidated affiliates	260.6	254.3		295.1
Other assets	0	0		0
Total assets	261.1	254.8		295.4
Current liabilities:
Accounts payable	0	0.1		0.2
Other current liabilities	0	0		0
Total current liabilities	0	0.1		0.2
Long-term liabilities:
Long-term debt, less current portion	0	0		0
Other long-term liabilities	0	0		0
Deferred income taxes	0	0		0
Partners' capital	75.5	71.2		123.5
Interest of non-controlling partners in subsidiaries	185.6	183.5		171.7
Total partners' capital	261.1	254.7		295.2
Total liabilities and partners' capital	$ 261.1	$ 254.8		$ 295.4

Condensed Consolidating Finan85

Condensed Consolidating Financial Information (Statements Of Operations) (Detail) - USD ($) $ in Millions	3 Months Ended									12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenues	$ 536	$ 629.1	$ 630.7	$ 641.5	$ 731.5	$ 994.9	$ 1,033.8	$ 923.9	$ 964.9	$ 2,632.8	$ 3,917.5	$ 1,412.6
Costs of product/services sold	363.4				529.7					1,883.5	3,154.8	995.4
Expenses:
Operations and maintenance	41.7				50.6					188.7	195.4	103.4
General and administrative	22.2				25.6					105.6	91.7	84.1
Depreciation, amortization and accretion	64.9				68.8					278.5	255.4	139.4
Costs and Expenses	128.8				145					572.8	542.5	326.9
Gain on long-lived assets, net					(0.8)					(227.8)	(35.1)	5.3
Goodwill impairment	(109.7)	(470.6)			0					(1,149.1)	(48.8)	(4.1)
Loss on contingent consideration										0	(8.6)	(31.4)
Operating income (loss)	(65.9)	(649.7)	(578.7)	(28)	56	(23.2)	54.6	41.6	54.7	(1,200.4)	127.7	60.1
Loss on long-lived assets, net					(0.8)					(227.8)	(35.1)	5.3
Operating income (loss)	(65.9)	(649.7)	(578.7)	(28)	56	(23.2)	54.6	41.6	54.7	(1,200.4)	127.7	60.1
Earnings from unconsolidated affiliates, net	6.5	(72)	2.8	5	3.4	0.6	0.3	(1.5)	(0.1)	(60.8)	(0.7)	(0.1)
Interest and debt expense, net	(36.1)				(29.9)					(130.5)	(111.4)	(71.7)
Loss on modification/extinguishment of debt										(18.9)	0	0
Equity in net income (loss) of subsidiary										0		0
Income (loss) before income taxes	(95.5)				29.5					(1,410.6)	15.6	(11.7)
Benefit for income taxes	(0.2)				0.4					0	0.9	0.7
Net income (loss)	(95.3)	(756.7)	(610.2)	(72.8)	29.1	(49.2)	27.1	11	25.8	(1,410.6)	14.7	(12.4)
Net income attributable to non-controlling partners	5.9				5.6					23.1	16.8	4.9
Net income (loss) attributable to Crestwood Midstream Partners LP	(101.2)				23.5					(1,433.7)	(2.1)	(17.3)
Net income attributable to Class A preferred units	0				9.2					23.1	17.2	0
Net income (loss) attributable to partners	(101.2)	$ (762.6)	$ (622.5)	$ (86)	14.3	$ (61.7)	$ 13.5	$ 6.2	$ 22.7	(1,456.8)	(19.3)	(17.3)
Eliminations
Revenues										0	0	0
Costs of product/services sold										0	0	0
Expenses:
Operations and maintenance										0	0	0
General and administrative										0	0	0
Depreciation, amortization and accretion										0	0	0
Costs and Expenses										0	0	0
Gain on long-lived assets, net										0	0	0
Goodwill impairment										0	0	0
Loss on contingent consideration											0	0
Operating income (loss)										0	0	0
Loss on long-lived assets, net										0	0	0
Operating income (loss)										0	0	0
Earnings from unconsolidated affiliates, net										0	0	0
Interest and debt expense, net										0	0	0
Loss on modification/extinguishment of debt										0
Equity in net income (loss) of subsidiary	41.5				(72.6)					1,195.9	(176.4)	(103.8)
Income (loss) before income taxes	41.5				(72.6)					1,195.9	(176.4)	(103.8)
Benefit for income taxes										0	0	0
Net income (loss)	41.5				(72.6)					1,195.9	(176.4)	(103.8)
Net income attributable to non-controlling partners											0	0
Net income (loss) attributable to Crestwood Midstream Partners LP	41.5				(72.6)					1,195.9	(176.4)	(103.8)
Net income attributable to Class A preferred units										0		0
Net income (loss) attributable to partners					(72.6)					1,195.9	(176.4)	(103.8)
Parent Company
Revenues										0	0	0
Costs of product/services sold										0	0	0
Expenses:
Operations and maintenance										0	0	0
General and administrative	17.7				13.4					65.3	49.4	46.5
Depreciation, amortization and accretion					0.2					0	0.9	1
Costs and Expenses	17.7				13.6					65.3	50.3	47.5
Gain on long-lived assets, net										0	0	0
Goodwill impairment										0	0	0
Loss on contingent consideration											0	0
Operating income (loss)	(17.7)				(13.6)					(65.3)	(50.3)	(47.5)
Loss on long-lived assets, net										0	0	0
Operating income (loss)	(17.7)				(13.6)					(65.3)	(50.3)	(47.5)
Earnings from unconsolidated affiliates, net										0	0	0
Interest and debt expense, net	(36.1)				(29.9)					(130.5)	(111.4)	(68.7)
Loss on modification/extinguishment of debt										(18.9)
Equity in net income (loss) of subsidiary	(41.5)				72.6					(1,195.9)	176.4	103.8
Income (loss) before income taxes	(95.3)				29.1					(1,410.6)	14.7	(12.4)
Benefit for income taxes										0	0	0
Net income (loss)	(95.3)				29.1					(1,410.6)	14.7	(12.4)
Net income attributable to non-controlling partners										0	0	0
Net income (loss) attributable to Crestwood Midstream Partners LP	(95.3)				29.1					(1,410.6)	14.7	(12.4)
Net income attributable to Class A preferred units					9.2					23.1	17.2	0
Net income (loss) attributable to partners					19.9					(1,433.7)	(2.5)	(12.4)
Guarantor Subsidiaries
Revenues	536				731.5					2,632.8	3,917.5	1,412.6
Costs of product/services sold	363.4				529.7					1,883.5	3,154.8	995.4
Expenses:
Operations and maintenance	41.7				50.6					188.7	195.4	103.4
General and administrative	4.5				12.2					40.3	42.3	37.6
Depreciation, amortization and accretion	64.9				68.6					278.5	254.5	138.4
Costs and Expenses	111.1				131.4					507.5	492.2	279.4
Gain on long-lived assets, net					(0.8)					(227.8)	(35.1)	5.3
Goodwill impairment	(109.7)									(1,149.1)	(48.8)	(4.1)
Loss on contingent consideration											(8.6)	(31.4)
Operating income (loss)	(48.2)				69.6					(1,135.1)	178	107.6
Loss on long-lived assets, net					(0.8)					(227.8)	(35.1)	5.3
Operating income (loss)	(48.2)				69.6					(1,135.1)	178	107.6
Earnings from unconsolidated affiliates, net										0	0	0
Interest and debt expense, net										0	0	(3)
Loss on modification/extinguishment of debt										0
Equity in net income (loss) of subsidiary										0	0	0
Income (loss) before income taxes	(48.2)				69.6					(1,135.1)	178	104.6
Benefit for income taxes	(0.2)				0.4					0	0.9	0.7
Net income (loss)	(48)				69.2					(1,135.1)	177.1	103.9
Net income attributable to non-controlling partners										0	0	0
Net income (loss) attributable to Crestwood Midstream Partners LP	(48)				69.2					(1,135.1)	177.1	103.9
Net income attributable to Class A preferred units										0		0
Net income (loss) attributable to partners					69.2					(1,135.1)	177.1	103.9
Non-Guarantor Subsidiaries
Revenues										0	0	0
Costs of product/services sold										0	0	0
Expenses:
Operations and maintenance										0	0	0
General and administrative										0	0	0
Depreciation, amortization and accretion										0	0	0
Costs and Expenses										0	0	0
Gain on long-lived assets, net										0	0	0
Goodwill impairment										0	0	0
Loss on contingent consideration											0	0
Operating income (loss)										0	0	0
Loss on long-lived assets, net										0	0	0
Operating income (loss)										0	0	0
Earnings from unconsolidated affiliates, net	6.5				3.4					(60.8)	(0.7)	(0.1)
Interest and debt expense, net										0	0	0
Loss on modification/extinguishment of debt										0
Equity in net income (loss) of subsidiary										0	0	0
Income (loss) before income taxes	6.5				3.4					(60.8)	(0.7)	(0.1)
Benefit for income taxes										0		0
Net income (loss)	6.5				3.4					(60.8)	(0.7)	(0.1)
Net income attributable to non-controlling partners	5.9				5.6					23.1	16.8	4.9
Net income (loss) attributable to Crestwood Midstream Partners LP	$ 0.6				(2.2)					(83.9)	(17.5)	(5)
Net income attributable to Class A preferred units										0		0
Net income (loss) attributable to partners					$ (2.2)					$ (83.9)	$ (17.5)	$ (5)

Condensed Consolidating Finan86

Condensed Consolidating Financial Information (Statements Of Cash Flows) (Detail) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	$ 135.7	$ 105.7	$ 471.8	$ 437.3	$ 253.7
Cash flows from investing activities:
Acquisitions, net of cash acquired			0	(19.5)	(561.5)
Purchases of property, plant and equipment	(55.6)	(47.4)	(182.7)	(421.7)	(339.3)
Investment in unconsolidated affiliates	(5.5)	(17.9)	(41.8)	(144.4)	(151.5)
Proceeds from the sale of assets	0.8	0.5	2.7	2.7	11.2
Capital distributions from unconsolidated affiliates			9.3	0	0
Capital contributions to consolidated affiliates	0	0
Other	0	(0.2)
Net cash provided by (used in) investing activities	(60.3)	(65)	(212.5)	(582.9)	(1,041.1)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	313.5	1,114.6	3,490.1	2,089.9	2,072.8
Principal payments on long-term debt	(286)	(970.4)	(2,960.9)	(1,950)	(1,634.5)
Payments on capital leases	(0.5)	(0.7)	(2.2)	(3.2)	(4.3)
Payments for debt-related deferred costs	(0.1)	(11.1)	(17.3)	(0.1)	(32)
Financing fees paid for early debt redemption			(13.6)	0	0
Distributions paid	(101)	(111.4)	(819.5)	(470.5)	(419.7)
Contributions from parent	0	0	0	0	5.5
Net proceeds from the issuance of common units					714
Contributions from parent			0	53.9	96.1
Net proceeds from issuance of Class A preferred units			58.8	430.5
Taxes paid for unit-based compensation vesting	(0.6)	(1.7)	(2.1)	(1.6)	(5.5)
Change in intercompany balances	0	0
Other	0	(0.2)	(0.1)	(0.8)	0
Net cash provided by (used in) financing activities	(74.7)	19.1	(266.8)	148.1	792.4
Net change in cash	0.7	59.8	(7.5)	2.5	5
Cash at beginning of period	0.1	7.6	7.6	5.1	0.1
Cash at end of period	0.8	67.4	0.1	7.6	5.1
Eliminations
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	0	0	0		(33.8)
Cash flows from investing activities:
Purchases of property, plant and equipment	0	0
Investment in unconsolidated affiliates	0	0
Proceeds from the sale of assets	0	0
Capital contributions to consolidated affiliates	3.7	17.9	31.2	89.5	106.4
Other		0
Net cash provided by (used in) investing activities	3.7	17.9	31.2	89.5	106.4
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	0	0
Principal payments on long-term debt	0	0
Payments on capital leases	0	0
Payments for debt-related deferred costs	0	0
Distributions paid	0	0			33.8
Contributions from parent	(3.7)	(17.9)		(89.5)	(106.4)
Contributions from parent			(31.2)
Taxes paid for unit-based compensation vesting	0	0
Change in intercompany balances	0	0
Other		0
Net cash provided by (used in) financing activities	(3.7)	(17.9)	(31.2)	(89.5)	(72.6)
Net change in cash	0	0
Cash at beginning of period	0	0	0
Cash at end of period	0	0	0	0
Parent Company
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	(42.7)	(54.8)	(190.8)	(165.6)	(46.1)
Cash flows from investing activities:
Purchases of property, plant and equipment	(0.9)	(0.1)	(0.8)	(4.3)	(1)
Investment in unconsolidated affiliates	0	0
Proceeds from the sale of assets	0	0
Capital contributions to consolidated affiliates	(3.7)	(17.9)	(31.2)	(89.5)	(106.4)
Other		0
Net cash provided by (used in) investing activities	(4.6)	(18)	(32)	(93.8)	(107.4)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	313.5	1,114.6	3,490.1	2,089.9	2,072.8
Principal payments on long-term debt	(286)	(970.4)	(2,960.9)	(1,949.8)	(1,634.3)
Payments on capital leases	0	(0.5)		(1.3)	(0.4)
Payments for debt-related deferred costs	(0.1)	(11.1)	(17.3)	(0.1)	(32)
Financing fees paid for early debt redemption			(13.6)
Distributions paid	(97.2)	(111.4)	(808.2)	(470.5)	(419.7)
Contributions from parent	0	0
Net proceeds from the issuance of common units					714
Net proceeds from issuance of Class A preferred units			58.8	430.5
Taxes paid for unit-based compensation vesting	0	0
Change in intercompany balances	117.8	51.8	474.1	161.4	(546.8)
Other		(0.2)	(0.1)	(0.8)
Net cash provided by (used in) financing activities	48	72.8	222.9	259.3	153.6
Net change in cash	0.7	0	0.1	(0.1)	0.1
Cash at beginning of period	0.1	0	0	0.1
Cash at end of period	0.8	0	0.1	0	0.1
Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	172.8	160.5	650	602.9	333.6
Cash flows from investing activities:
Acquisitions, net of cash acquired				(19.5)	(561.5)
Purchases of property, plant and equipment	(54.7)	(47.3)	(181.9)	(417.4)	(338.3)
Investment in unconsolidated affiliates	0	0
Proceeds from the sale of assets	0.8	0.5	2.7	2.7	11.2
Capital contributions to consolidated affiliates	0	0
Other		(0.2)
Net cash provided by (used in) investing activities	(53.9)	(47)	(179.2)	(434.2)	(888.6)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	0	0
Principal payments on long-term debt	0	0		(0.2)	(0.2)
Payments on capital leases	(0.5)	(0.2)	(2.2)	(1.9)	(3.9)
Payments for debt-related deferred costs	0	0
Distributions paid	0	0			(33.8)
Contributions from parent	0	0			55.5
Taxes paid for unit-based compensation vesting	(0.6)	(1.7)	(2.1)	(1.6)	(5.5)
Change in intercompany balances	(117.8)	(51.8)	(474.1)	(161.4)	546.8
Other		0
Net cash provided by (used in) financing activities	(118.9)	(53.7)	(478.4)	(165.1)	558.9
Net change in cash	0	59.8	(7.6)	3.6	3.9
Cash at beginning of period	0	7.6	7.6	4	0.1
Cash at end of period	0	67.4	0	7.6	4
Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	5.6	0	12.6
Cash flows from investing activities:
Purchases of property, plant and equipment	0	0
Investment in unconsolidated affiliates	(5.5)	(17.9)	(41.8)	(144.4)	(151.5)
Proceeds from the sale of assets	0	0
Capital distributions from unconsolidated affiliates			9.3
Capital contributions to consolidated affiliates	0	0
Other		0
Net cash provided by (used in) investing activities	(5.5)	(17.9)	(32.5)	(144.4)	(151.5)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	0	0
Principal payments on long-term debt	0	0
Payments on capital leases	0	0
Payments for debt-related deferred costs	0	0
Distributions paid	(3.8)	0	(11.3)
Contributions from parent	3.7	17.9		89.5	56.4
Contributions from parent			31.2	53.9	96.1
Taxes paid for unit-based compensation vesting	0	0
Change in intercompany balances	0	0
Other		0
Net cash provided by (used in) financing activities	(0.1)	17.9	19.9	143.4	152.5
Net change in cash	0	0		(1)	1
Cash at beginning of period	0	0	0	1
Cash at end of period	$ 0	$ 0	$ 0	$ 0	$ 1

Supplemental Quarterly Data (De

Supplemental Quarterly Data (Detail) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended									12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenues	$ 536	$ 629.1	$ 630.7	$ 641.5	$ 731.5	$ 994.9	$ 1,033.8	$ 923.9	$ 964.9	$ 2,632.8	$ 3,917.5	$ 1,412.6
Operating income (loss)	(65.9)	(649.7)	(578.7)	(28)	56	(23.2)	54.6	41.6	54.7	(1,200.4)	127.7	60.1
Earnings (loss) from unconsolidated affiliates, net	6.5	(72)	2.8	5	3.4	0.6	0.3	(1.5)	(0.1)	(60.8)	(0.7)	(0.1)
Net income (loss)	(95.3)	(756.7)	(610.2)	(72.8)	29.1	(49.2)	27.1	11	25.8	(1,410.6)	14.7	(12.4)
Net income (loss) attributable to partners	(101.2)	(762.6)	(622.5)	(86)	14.3	(61.7)	13.5	6.2	22.7	(1,456.8)	(19.3)	(17.3)
Crestwood Equity Partners LP
Revenues	536	629.1	630.7	641.5	731.5	997.2	1,036.2	926.3	971.6	2,632.8	3,931.3	1,426.7
Operating income (loss)	(64.2)	(1,296.1)	(588.3)	(248.9)	48.5	(0.2)	43	29.4	45.7	(2,084.8)	117.9	28.2
Earnings (loss) from unconsolidated affiliates, net	6.5	(72)	2.8	5	3.4	0.6	0.3	(1.5)	(0.1)	(60.8)	(0.7)	(0.1)
Net income (loss)	(93.7)	(1,402.4)	(623.4)	(296)	18.1	(30.7)	11.9	(4.8)	13.2	(2,303.7)	(10.4)	(50.6)
Net income (loss) attributable to partners	$ (101.2)	$ (1,414.5)	$ (226.9)	$ (40)	$ 8.3	$ 38.4	$ 2.8	$ (4.4)	$ 19.6	$ (1,673.1)	$ 56.4	$ 6.7
Basic	$ (1.47)	$ (20.77)	$ (11.78)	$ (2.14)	$ 0.44	$ 2.06	$ 0.15	$ (0.24)	$ 1.05	$ (54)	$ 3.03	$ 0.59
Diluted	$ (1.47)	$ (20.77)	$ (11.76)	$ (2.14)	$ 0.44	$ 2.06	$ 0.15	$ (0.24)	$ 1.05	$ (54)	$ 3.03	$ 0.59

Supplemental Quarterly Data (Pa

Supplemental Quarterly Data (Parenthetical) (Detail) - USD ($) $ in Millions	1 Months Ended	3 Months Ended						12 Months Ended
	Dec. 31, 2014	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Impaired assets to be disposed of			$ 694.3	$ 610.8	$ 68.6		$ 83.3	$ 354.4
Gain from unconsolidated affiliates, net		$ 0				$ (0.8)		227.8	$ 35.1	$ (5.3)
Jackalope Gas Gathering Services, L.L.C.
Equity method investment, other than temporary impairment			51.4					51.4
Powder River Basin Industrial Complex, LLC
Equity method investment, other than temporary impairment			23.4					$ 23.4
Tres Palacios Holdings LLC
Impaired assets to be disposed of			$ 1,332.3	$ 610.8	$ 281		$ 83.3
Gain from unconsolidated affiliates, net	$ 30.6								$ 30.6

Schedule I - Crestwood Equity89

Schedule I - Crestwood Equity Partners LP - Parent Only - Balance Sheet (Detail) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Assets
Cash	$ 0.8	$ 0.1	$ 67.4	$ 7.6	$ 5.1	$ 0.1
Total current assets	270.3	333.6		536.6
Property, plant and equipment, net	3,514.4	3,525.7		3,746
Intangible assets		1,887.8		3,204.2
Investment in subsidiaries	0	0		0
Total assets	5,767.4	5,963.6		7,785.2
Liabilities and partners' capital
Accrued expenses	94.6	103.3		150.1
Current portion of long-term debt	0.9	0.9		0.8
Total current liabilities	219.3	253		411.3
Long-term debt, less current portion	2,530.8	2,501.8		2,014.5
Other long-term liabilities	44.1	43.3		38.3
Total partners' capital	2,972.6	3,165.1		5,320.4	5,291.3	859.7
Total liabilities and partners' capital	5,767.4	5,963.6		7,785.2
Crestwood Equity Partners LP
Assets
Cash	1.1	0.5	$ 67.7	8.8	5.2	0.1
Total current assets	272.4	335.8		538.1
Property, plant and equipment, net	3,303	3,310.8		3,893.8
Total assets	5,570	5,762.8		8,461.4
Liabilities and partners' capital
Accrued expenses	96.8	105.6		154.6
Current portion of long-term debt	0.9	1.1		3.7
Total current liabilities	224.1	258.2		424.9
Long-term debt, less current portion	2,530.8	2,501.8		2,392.8
Other long-term liabilities	48.2	47.5		47.2
Total partners' capital	2,758.6	2,946.9		5,584.5	5,508.6	1,550.7
Total liabilities and partners' capital	$ 5,570	5,762.8		8,461.4
Crestwood Equity Partners LP | Parent Company
Assets
Cash		0.4		3.7	$ 0.1	$ 0
Accounts receivable-trade		1.8		0
Accounts receivable-intercompany		0		3.2
Total current assets		2.2		6.9
Property, plant and equipment, net		1.5		2.5
Intangible assets		7.8		1.7
Investment in subsidiaries		2,757.7		5,799.5
Other assets		3.5		0
Total assets		2,772.7		5,810.6
Liabilities and partners' capital
Accounts payable		2.6		0
Accrued expenses		2.3		1.9
Current portion of long-term debt		0.2		3
Total current liabilities		5.1		4.9
Long-term debt, less current portion		0		380
Other long-term liabilities		4.2		12.9
Total partners' capital		2,763.4		5,412.8
Total liabilities and partners' capital		$ 2,772.7		$ 5,810.6

Schedule I - Crestwood Equity90

Schedule I - Crestwood Equity Partners LP - Parent Only - Statement of Operations (Detail) - USD ($) $ in Millions	3 Months Ended									12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
Revenues	$ 536	$ 629.1	$ 630.7	$ 641.5	$ 731.5	$ 994.9	$ 1,033.8	$ 923.9	$ 964.9	$ 2,632.8	$ 3,917.5	$ 1,412.6
Costs and Expenses	128.8				145					572.8	542.5	326.9
Operating income (loss)	(65.9)	(649.7)	(578.7)	(28)	56	(23.2)	54.6	41.6	54.7	(1,200.4)	127.7	60.1
Interest and debt expense, net	(36.1)				(29.9)					(130.5)	(111.4)	(71.7)
Loss from unconsolidated affiliates										0		0
Loss on modification/extinguishment of debt										18.9	0	0
Income (loss) before income taxes	(95.5)				29.5					(1,410.6)	15.6	(11.7)
Provision (benefit) for income taxes	(0.2)				0.4					0	0.9	0.7
Net loss	(95.3)	(756.7)	(610.2)	(72.8)	29.1	(49.2)	27.1	11	25.8	(1,410.6)	14.7	(12.4)
Net income attributable to non-controlling partners in subsidiary	(5.9)				(5.6)					(23.1)	(16.8)	(4.9)
Net income (loss) attributable to parent	(101.2)				23.5					(1,433.7)	(2.1)	(17.3)
Crestwood Equity Partners LP
Condensed Financial Statements, Captions [Line Items]
Revenues	536	629.1	630.7	641.5	731.5	997.2	1,036.2	926.3	971.6	2,632.8	3,931.3	1,426.7
Operating income (loss)	(64.2)	(1,296.1)	(588.3)	(248.9)	48.5	(0.2)	43	29.4	45.7	(2,084.8)	117.9	28.2
Interest and debt expense, net	(36.1)				(33.6)					(140.1)	(127.1)	(77.9)
Loss on modification/extinguishment of debt										20	0	0
Other income, net	0.1				0.2					0.6	0.6	0.2
Income (loss) before income taxes	(93.7)				18.5					(2,305.1)	(9.3)	(49.6)
Provision (benefit) for income taxes	0				0.4					(1.4)	1.1	1
Net loss	(93.7)	$ (1,402.4)	$ (623.4)	$ (296)	18.1	$ (30.7)	$ 11.9	$ (4.8)	$ 13.2	(2,303.7)	(10.4)	(50.6)
Net income attributable to non-controlling partners in subsidiary	(5.9)				(9.8)					636.8	66.8	57.3
Net income (loss) attributable to parent	$ (99.6)				$ 8.3					(1,666.9)	56.4	6.7
Crestwood Equity Partners LP | Parent Company
Condensed Financial Statements, Captions [Line Items]
Revenues										0	0	0
Costs and Expenses										14.5	8.5	0
Operating income (loss)										(14.5)	(8.5)	0
Interest and debt expense, net										(9.6)	(15.7)	(6.5)
Loss from unconsolidated affiliates										(2,279.1)	14.2	(43.9)
Loss on modification/extinguishment of debt										(1.1)	0	0
Other income, net										0.6	0	0
Income (loss) before income taxes										(2,303.7)	(10)	(50.4)
Provision (benefit) for income taxes										0	0.4	0.2
Net loss										(2,303.7)	(10.4)	(50.6)
Net income attributable to non-controlling partners in subsidiary										(6.2)	0	0
Net income (loss) attributable to parent										$ (2,309.9)	$ (10.4)	$ (50.6)

Schedule I - Crestwood Equity91

Schedule I - Crestwood Equity Partners LP - Parent Only - Statement of Comprehensive Income (Detail) - USD ($) $ in Millions	3 Months Ended									12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
Net loss	$ (95.3)	$ (756.7)	$ (610.2)	$ (72.8)	$ 29.1	$ (49.2)	$ 27.1	$ 11	$ 25.8	$ (1,410.6)	$ 14.7	$ (12.4)
Crestwood Equity Partners LP
Condensed Financial Statements, Captions [Line Items]
Net loss	(93.7)	$ (1,402.4)	$ (623.4)	$ (296)	18.1	$ (30.7)	$ 11.9	$ (4.8)	$ 13.2	(2,303.7)	(10.4)	(50.6)
Change in fair value of Suburban Propane Partners, LP units	0.8				0					(2.7)	(0.5)	(0.1)
Comprehensive income (loss) attributable to Crestwood Equity Partners LP	$ (98.8)				$ 8.3					(1,669.6)	55.9	6.6
Crestwood Equity Partners LP | Parent Company
Condensed Financial Statements, Captions [Line Items]
Net loss										(2,303.7)	(10.4)	(50.6)
Change in fair value of Suburban Propane Partners, LP units										(2.7)	(0.5)	(0.1)
Comprehensive income (loss) attributable to Crestwood Equity Partners LP										$ (2,306.4)	$ (10.9)	$ (50.7)

Schedule I - Crestwood Equity92

Schedule I - Crestwood Equity Partners LP - Parent Only - Condensed Statement of Cash Flows (Detail) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	$ 135.7	$ 105.7	$ 471.8	$ 437.3	$ 253.7
Cash flows from investing activities	(60.3)	(65)	(212.5)	(582.9)	(1,041.1)
Proceeds from the issuance of long-term debt	313.5	1,114.6	3,490.1	2,089.9	2,072.8
Principal payments on long-term debt	(286)	(970.4)	(2,960.9)	(1,950)	(1,634.5)
Payments for debt-related deferred costs	(0.1)	(11.1)	(17.3)	(0.1)	(32)
Distributions to partners	(101)	(111.4)	(819.5)	(470.5)	(419.7)
Change in intercompany balances	0	0
Other	0	(0.2)	(0.1)	(0.8)	0
Net cash used in financing activities	(74.7)	19.1	(266.8)	148.1	792.4
Net change in cash	0.7	59.8	(7.5)	2.5	5
Cash at beginning of period	0.1	7.6	7.6	5.1	0.1
Cash at end of period	0.8	67.4	0.1	7.6	5.1
Crestwood Equity Partners LP
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	134.3	156.6	440.7	283	188.3
Cash flows from investing activities	(60.3)	(65.2)	(212.7)	(483)	(1,042.9)
Proceeds from the issuance of long-term debt	313.5	1,252.7	4,261.8	2,823.9	2,466.9
Principal payments on long-term debt	(286.2)	(1,169.9)	(4,113)	(2,696)	(1,967.6)
Payments for debt-related deferred costs	(0.1)	(11.1)	(17.3)	(1.9)	(33.1)
Distributions to partners	(95.6)	(25.8)	(171.5)	(102.5)	(68.4)
Other	(0.1)	(0.3)	(1.3)	(0.7)	0.1
Net cash used in financing activities	(73.4)	(32.5)	(236.3)	203.6	859.7
Net change in cash	0.6	58.9	(8.3)	3.6	5.1
Cash at beginning of period	0.5	8.8	8.8	5.2	0.1
Cash at end of period	1.1	67.7	0.5	8.8	5.2
Crestwood Equity Partners LP | Parent Company
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities			(14.7)	(25.3)	(12.3)
Cash flows from investing activities			593.8	170.8	20.7
Proceeds from the issuance of long-term debt			771.7	734	394.1
Principal payments on long-term debt			(1,152.1)	(746.2)	(333.3)
Payments for debt-related deferred costs			0	(1.8)	0
Distributions to partners			(171.5)	(102.5)	(68.4)
Change in intercompany balances			(30.5)	(25.4)	0.4
Other			0	0	(1.1)
Net cash used in financing activities			(582.4)	(141.9)	(8.3)
Net change in cash			(3.3)	3.6	0.1
Cash at beginning of period	$ 0.4	$ 3.7	3.7	0.1	0
Cash at end of period			$ 0.4	$ 3.7	$ 0.1

Schedule I - Crestwood Equity93

Schedule I - Crestwood Equity Partners LP - Parent Only (Distributions) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Crestwood Equity Partners LP
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Dividends received from CMLP	$ 31.4	$ 72.4	$ 26.2

Schedule II - Crestwood Equity

Schedule II - Crestwood Equity Partners LP - Valuation and Qualifying Accounts (Details) - Allowance for Doubtful Accounts - USD ($)Schedule II - Crestwood Equity Partners LP - Valuation and Qualifying Accounts - Allowance for Doubtful Accounts (Detail) - Crestwood Equity Partners LP - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Movement in Valuation Allowances and Reserves [Roll Forward]
Valuation Allowances and Reserves, Balance	$ 0.1	$ 0.1	$ 0
Valuation Allowances and Reserves, Charged to Cost and Expense	0	0	(1.1)
Valuation Allowances and Reserves, Charged to Other Accounts	0.4	0	1.2
Valuation Allowances and Reserves, Deductions	(0.1)	0	0
Valuation Allowances and Reserves, Balance	$ 0.4	$ 0.1	$ 0.1

Partners' Capital (Components o

Partners' Capital (Components of Net Income (Loss) Attributable to Non-Controlling Interests) (Detail) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Distribution Made to Limited Partner [Line Items]
CEQP net income attributable to non-controlling partners	$ 5.9	$ 5.6	$ 23.1	$ 16.8	$ 4.9
Limited Partner
Distribution Made to Limited Partner [Line Items]
CEQP net income attributable to non-controlling partners	0	(5)
Preferred Units, Class A
Distribution Made to Limited Partner [Line Items]
CEQP net income attributable to non-controlling partners	0	9.2	23.1	17.2	0
Crestwood Niobrara LLC
Distribution Made to Limited Partner [Line Items]
CEQP net income attributable to non-controlling partners	5.9	5.6	23.1	16.8	4.9
Crestwood Equity Partners LP
Distribution Made to Limited Partner [Line Items]
CEQP net income attributable to non-controlling partners	$ 5.9	$ 9.8	$ (636.8)	$ (66.8)	$ (57.3)

Subsequent Events (Detail)

Subsequent Events (Detail) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		12 Months Ended
	Apr. 30, 2016	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Subsequent Event [Line Items]
Proceeds from sale of assets		$ 0.8	$ 0.5	$ 2.7	$ 2.7	$ 11.2
Subsequent Event
Subsequent Event [Line Items]
Proceeds from sale of assets	$ 975
CEGP | Subsequent Event
Subsequent Event [Line Items]
Ownership Percentage	50.00%