Crestwood Equity Partners (CEQP) 10-Q 8 Nov 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2013
Entity Information [Line Items]	'
Document Type	'10-Q
Amendment Flag	'false
Document Period End Date	30-Sep-13
Document Fiscal Year Focus	'2013
Document Fiscal Period Focus	'Q3
Trading Symbol	'CEQP
Entity Registrant Name	'Crestwood Equity Partners LP
Entity Central Index Key	'0001136352
Current Fiscal Year End Date	'--12-31
Entity Filer Category	'Large Accelerated Filer
Entity Common Stock, Shares Outstanding	0

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Assets	'	'
Cash and cash equivalents	$8.80	$0.10
Accounts receivable, less allowance for doubtful accounts of $0.1 million at September 30, 2013	238.9	45.4
Inventory (Note 3)	95.7	0
Assets from price risk management activities	23.7	0
Prepaid expenses and other current assets	20.1	4.9
Total current assets	387.2	50.4
Property, plant and equipment (Note 3)	3,727.90	1,197.40
Less: accumulated depreciation	167.8	95
Property, plant and equipment, net	3,560.10	1,102.40
Intangible assets (Note 3)	1,098.90	845.2
Less: accumulated amortization	84.8	49.9
Intangible assets, net	1,014.10	795.3
Goodwill	2,921.20	352.2
Investment in unconsolidated affiliates	152.1	0
Other assets	15.7	1.3
Total assets	8,050.40	2,301.60
Current liabilities:	'	'
Accounts payable	212.1	5.4
Accrued expenses and other liabilities	148.5	43.1
Liabilities from price risk management activities	31.9	0
Current portion of long-term debt (Note 7)	4.4	0
Total current liabilities	396.9	48.5
Long-term debt, less current portion (Note 7)	1,827.40	685.2
Other long-term liabilities	204.8	17.2
Deferred income taxes	17.4	0
Partners’ capital (Note 8):	'	'
Limited partner unitholders (171,059,307 and 39,491,002 limited partner units issued and outstanding at September 30, 2013 and December 31, 2012, respectively)	1,367.80	31.7
Total Crestwood Equity Partners LP partners’ capital	1,367.80	31.7
Interest of non-controlling partners in subsidiaries	4,236.10	1,519
Total partners’ capital	5,603.90	1,550.70
Total liabilities and partners’ capital	$8,050.40	$2,301.60

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified
Allowance for doubtful accounts	$0.10	$0
Common units, issued	171,059,307	39,491,002
Common units, outstanding	171,059,307	39,491,002

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	3 Months Ended		9 Months Ended
In Millions, except Share data in Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Revenues:	'	'	'	'
Gathering and processing	$71.10	$63	$214.60	$172
NGL and crude services	307.3	0	348.8	0
Storage and transportation	48.8	0	55.1	0
Total revenue	427.2	63	618.5	172
Cost of product/services sold (excluding depreciation, amortization and accretion as shown below):	'	'	'	'
Gathering and processing	12.9	10.3	40.4	26.7
NGL and crude services	270	0	307.4	0
Storage and transportation	7.1	0	7.7	0
Cost of product/services sold	290	10.3	355.5	26.7
Expenses:	'	'	'	'
Operating and administrative	66.3	17.5	118.2	52
Depreciation, amortization and accretion	55.4	16.9	105.8	51.9
Total Expenses	121.7	34.4	224	103.9
Goodwill impairment	-4.1	0	-4.1	0
Gain on sale of assets	4.4	0	4.4	0
Gain on contingent consideration	0	0	0	6.8
Operating income	15.8	18.3	39.3	48.2
Loss from unconsolidated affiliate	0.4	0	0.4	0
Other income (expense):	'	'	'	'
Interest and debt expense, net	22.8	8.9	46.2	25.4
Income (loss) before income taxes	-7.4	9.4	-7.3	22.8
Provision for income taxes	0.5	0.3	1.2	0.9
Net income (loss)	-7.9	9.1	-8.5	21.9
Net (income) loss attributable to non-controlling partners	-0.4	-3.1	6.9	-9.2
Net income (loss) attributable to Crestwood Equity Partners LP	-8.3	6	-1.6	12.7
Subordinated unitholders' interest in net income (loss)	-0.2	0.7	-0.1	1.4
Common unitholders' interest in net income (loss)	($8.10)	$5.30	($1.50)	$11.30
Net income (loss) per limited partner unit:	'	'	'	'
Basic (dollars per unit)	-0.05	0.15	-0.02	0.32
Diluted (dollars per unit)	-0.05	0.15	-0.02	0.32
Weighted-average limited partners’ units outstanding (in thousands):	'	'	'	'
Basic (units)	166,720	35,103	85,243	35,103
Dilutive (units)	4,388	4,388	4,388	4,388
Diluted (units)	171,108	39,491	89,631	39,491

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Net income (loss)	($7.90)	$9.10	($8.50)	$21.90
Change in Suburban Propane Partners, L.P. units (Note 2)	0.2	0	0	0
Comprehensive income (loss)	($7.70)	$9.10	($8.50)	$21.90

Consolidated_Statement_of_Part

Consolidated Statement of Partners' Capital (USD $)

Total

Limited Partners

Non-Controlling Partners

Inergy Midstream

Inergy Midstream

Inergy Midstream

Crestwood Marcellus Midstream LLC

Crestwood Marcellus Midstream LLC

Crestwood Marcellus Midstream LLC

Class D Units

Class D Units

Class D Units

Class C Units

Class C Units

Class C Units

In Millions, unless otherwise specified

Limited Partners

Non-Controlling Partners

Limited Partners

Non-Controlling Partners

Limited Partners

Non-Controlling Partners

Limited Partners

Non-Controlling Partners

Balance at December 31, 2012 at Dec. 31, 2012

$1,550.70

$31.70

$1,519

'

'

'

'

'

'

'

'

'

'

'

'

Increase (Decrease) in Partners' Capital [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds from issuance of common units by subsidiaries

'

'

'

356.7

0

356.7

'

'

'

0

-126.3

126.3

0

0.6

-0.6

Net proceeds from common unit options exercised

0.1

0.1

0

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of preferred equity of subsidiary

96.1

0

96.1

'

'

'

'

'

'

'

'

'

'

'

'

Gain (loss) on issuance of subsidiary units

0

-4

4

'

'

'

'

'

'

'

'

'

'

'

'

Change in interest in Crestwood Marcellus Midstream LLC

'

'

'

'

'

'

0

238.9

-238.9

'

'

'

'

'

'

Invested capital from Crestwood Equity Partners LP net of debt (Note 4)

0

'

'

'

'

'

3,873.20

1,388.80

2,484.40

'

'

'

'

'

'

Unit-based compensation charges

7.6

1

6.6

'

'

'

'

'

'

'

'

'

'

'

'

Taxes paid for unit-based compensation vesting

-1.4

-0.7

-0.7

'

'

'

'

'

'

'

'

'

'

'

'

Distributions to members

-141.6

-31.6

-110

'

'

'

-129

-129

0

'

'

'

0

-0.1

0.1

Net income (loss)

-8.5

-1.6

-6.9

'

'

'

'

'

'

'

'

'

'

'

'

Balance at September 30, 2013 at Sep. 30, 2013

$5,603.90

$1,367.80

$4,236.10

'

'

'

'

'

'

'

'

'

'

'

'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
			Inergy Midstream	Inergy Midstream	CMLP	CMLP	Crestwood Marcellus Midstream LLC	Crestwood Marcellus Midstream LLC
Operating activities	'	'	'	'	'	'	'	'
Net income (loss)	($8.50)	$21.90	'	'	'	'	'	'
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'	'	'	'	'	'
Depreciation and depletion	73.7	34.9	'	'	'	'	'	'
Amortization and accretion	32.1	17	'	'	'	'	'	'
Amortization of deferred financing costs	3.4	3.7	'	'	'	'	'	'
Amortization of bond premium	-0.4	0	'	'	'	'	'	'
Market adjustment on interest rate swaps	-1.1	0	'	'	'	'	'	'
Gain on contingent consideration	0	-6.8	'	'	'	'	'	'
Unit-based compensation charges	7.6	1.5	'	'	'	'	'	'
Provision for doubtful accounts	-1.1	0	'	'	'	'	'	'
Goodwill impairment	4.1	0	'	'	'	'	'	'
Gain on sale of assets	-4.4	0	'	'	'	'	'	'
Loss from unconsolidated affiliate	0.4	0	'	'	'	'	'	'
Deferred income taxes	-2.6	0	'	'	'	'	'	'
Other non-cash income items	-0.1	0	'	'	'	'	'	'
Changes in operating assets and liabilities, net of effects from acquisitions:	'	'	'	'	'	'	'	'
Accounts receivable	-61.8	-0.3	'	'	'	'	'	'
Inventory	-47.2	0	'	'	'	'	'	'
Prepaid expenses and other current assets	2.2	0.8	'	'	'	'	'	'
Accounts payable, accrued expenses and other liabilities	102.4	5.2	'	'	'	'	'	'
Net liabilities from price risk management activities	15.4	0	'	'	'	'	'	'
Net cash provided by operating activities	114.1	77.9	'	'	'	'	'	'
Investing activities	'	'	'	'	'	'	'	'
Acquisitions, net of cash acquired	6.1	-469	'	'	'	'	'	'
Purchases of property, plant and equipment	-198.6	-34.3	'	'	'	'	'	'
Proceeds from sale of assets	11.1	0	'	'	'	'	'	'
Investment in unconsolidated affiliates	-152.5	0	'	'	'	'	'	'
Net cash used in investing activities	-333.9	-503.3	'	'	'	'	'	'
Financing activities	'	'	'	'	'	'	'	'
Proceeds from the issuance of long-term debt	216.3	0	93.8	0	343.5	350.2	139.9	27.5
Principal payments on long-term debt	-160.2	0	-299.5	0	-194	-329.5	-75	-8
Contributions from partners	0	249.7	'	'	'	'	-3,873.20	'
Distributions to members	-43.4	-9.7	'	'	'	'	'	'
Distributions paid to non-controlling partners	-110	-63.9	'	'	'	'	'	'
Distributions for additional interest in Crestwood Marcellus Midstream LLC	-129	0	'	'	'	'	'	'
Payments on capital leases	-3	-2.2	'	'	'	'	'	'
Payments for deferred financing costs	-0.1	-6.5	'	'	'	'	'	'
Net proceeds from issuance of Crestwood Midstream Partners LP common units	118.5	217.5	'	'	'	'	'	'
Net proceeds from issuance of Inergy Midstream, L.P. common units	'	'	238.2	0	'	'	'	'
Issuance of preferred equity of subsidiary	96.1	'	'	'	'	'	'	'
Proceeds from issuance of preferred equity of subsidiary, net	'	0	'	'	'	'	'	'
Net proceeds from Crestwood Equity Partners LP common unit options exercised	0.1	0	'	'	'	'	'	'
Taxes paid for unit-based compensation vesting	-3.7	-0.4	'	'	'	'	'	'
Net cash provided by financing activities	228.5	424.7	'	'	'	'	'	'
Net increase (decrease) in cash	8.7	-0.7	'	'	'	'	'	'
Cash at beginning of period	0.1	0.8	'	'	'	'	'	'
Cash at end of period	8.8	0.1	'	'	'	'	'	'
Supplemental schedule of noncash investing and financing activities	'	'	'	'	'	'	'	'
Net change to property, plant and equipment through accounts payable and accrued expenses	-38.6	1.2	'	'	'	'	'	'
Acquisitions, net of cash acquired:	'	'	'	'	'	'	'	'
Current assets	216.6	0	'	'	'	'	'	'
Property, plant and equipment	2,259.70	132.1	'	'	'	'	'	'
Intangible assets	315	338.2	'	'	'	'	'	'
Goodwill	2,564.40	0	'	'	'	'	'	'
Other assets	12.7	0	'	'	'	'	'	'
Current liabilities	-208.9	-0.7	'	'	'	'	'	'
Debt	-1,079.30	-0.6	'	'	'	'	'	'
Invested capital of Crestwood Equity Partners LP, net of debt (Note 4)	-3,873.20	0	'	'	'	'	'	'
Other liabilities	-213.1	0	'	'	'	'	'	'
Total acquisitions, net of cash acquired	($6.10)	$469	'	'	'	'	'	'

Partnership_Organization_and_B

Partnership Organization and Basis of Presentation	9 Months Ended
	Sep. 30, 2013
Disclosure Partnership Organization And Basis Of Presentation Narrative [Abstract]	'
Partnership Organization and Basis of Presentation	'
	Partnership Organization and Basis of Presentation
	Organization
	Crestwood Equity Partners LP (formerly known as Inergy, L.P., the “Company” or “CEQP”), a Delaware limited partnership formed in March 2001, is an energy midstream company. Its common units are listed on the New York Stock Exchange (“NYSE”) under the symbol “CEQP.” The Company is managed by its general partner, Crestwood Equity GP LLC (formerly known as Inergy GP, LLC), which is indirectly owned by Crestwood Holdings LLC (“Crestwood Holdings”). The substantial majority of Crestwood Holdings is indirectly owned by First Reserve Management, LP, an energy-focused private equity fund (“FRC”).
	During the period ended September 30, 2013, the Company conducted a significant part of its consolidated operations through two publicly-traded master limited partnerships, Inergy Midstream, L.P. (“Inergy Midstream” or “NRGM”) and Crestwood Midstream Partners LP (“Legacy Crestwood” or “Legacy CMLP”). These master limited partnerships were managed by their general partners, and the Company owns the general partners of Inergy Midstream and Legacy Crestwood. The Company therefore managed and controlled Inergy Midstream and Legacy Crestwood.
	In addition to managing and controlling both NRGM and Legacy CMLP, the Company owned the incentive distribution rights (“IDRs”) of Inergy Midstream and Legacy Crestwood. The IDRs of Inergy Midstream entitle the Company to receive 50% of all distributions paid by Inergy Midstream in excess of its initial quarterly distribution of $0.37 per common unit. The general partner interest of Legacy CMLP entitled the Company to receive 1.8% of all distributions paid by Legacy CMLP. The IDRs of Legacy CMLP entitled the Company to receive 15% of all distributions above the first target distribution ($0.345 per common unit), 25% of all distributions above the second target distribution ($0.375 per common unit) and thereafter 50% of all distributions above the third target distribution level of $0.45 per common unit.
	On October 7, 2013, (i) Legacy Crestwood merged with a wholly-owned subsidiary of Inergy Midstream (the "Crestwood Merger"), with Legacy Crestwood continuing as the surviving entity; (ii) Legacy Crestwood merged with and into Inergy Midstream, with Inergy Midstream continuing as the surviving entity; and (iii) Inergy Midstream changed its name to Crestwood Midstream Partners LP and changed its NYSE listing symbol from “NRGM” to “CMLP.” Concurrently with these transactions, on October 7, 2013, the Company changed its name from Inergy, L.P. to Crestwood Equity Partners LP and changed its NYSE listing symbol from “NRGY” to “CEQP.” See "Business Combinations" below and Note 13 for additional information.
	Unless otherwise indicated, references in this report to “we,” “us,” “our,” “ours,” “our company,” the “Company,” 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) Inergy Midstream and NRGM refers to either Inergy Midstream, L.P. itself or Inergy Midstream, L.P. and its consolidated subsidiaries prior to the Crestwood Merger, (ii) Legacy Crestwood and Legacy CMLP refers to either Crestwood Midstream Partners LP itself or Crestwood Midstream Partners LP and its consolidated subsidiaries prior to the Crestwood Merger, and (iii) Crestwood Midstream and CMLP refers to either Crestwood Midstream Partners LP itself or Crestwood Midstream Partners LP and its consolidated subsidiaries subsequent to the Crestwood Merger, in each case, as the context requires.
	Business Combination
	On May 5, 2013, the Company and certain of its affiliates entered into a series of definitive agreements with Crestwood Holdings and certain of its affiliates under which, among other things, (i) the Company agreed to distribute to its common unitholders all of the NRGM common units owned by the Company; (ii) Crestwood Holdings agreed to acquire the owner of our general partner; (iii) Crestwood Holdings agreed to contribute ownership of Legacy CMLP's general partner and IDRs to the Company in exchange for common and subordinated units of the Company; and (iv) Legacy Crestwood agreed to merge with and into a subsidiary of Inergy Midstream in a merger in which Legacy CMLP unitholders received 1.07 NRGM common units for each Legacy CMLP common unit they owned and, Legacy CMLP unitholders (other than Crestwood Holdings), received a one-time approximately $35 million cash payment at the closing of the Merger, or $1.03 per unit, $25 million of which was paid by NRGM and approximately $10 million of which was paid by Crestwood Holdings.
	On June 5, 2013, Legacy Crestwood's general partner distributed to a wholly-owned subsidiary of Crestwood Holdings approximately 137,105 common units and approximately 21,588 Class D units of Legacy CMLP, representing all of the Legacy CMLP common and Class D units held by Legacy Crestwood's general partner.
	On June 18, 2013, the Company distributed to its unitholders approximately 56.4 million NRGM common units, representing all of the NRGM common units held by the Company.
	On June 19, 2013, Crestwood Holdings acquired the owner of our general partner and contributed to the Company ownership of Crestwood Gas Services GP, LLC ("Legacy CMLP GP"), which owned 100% of the general partnership interests and IDRs of Legacy Crestwood. Crestwood Holdings and its ultimate parent company, FRC, acquired control of the Company as a result of these transactions.
	On October 7, 2013, the Crestwood Merger closed. As a result of the completion of the Crestwood Merger and certain related transactions on October 7, 2013, the operations of Inergy Midstream and Legacy CMLP have now been combined. The Company continues to own (i) the general partner of Crestwood Midstream, which entitles us to manage and control the master limited partnership, and (ii) the IDRs of Crestwood Midstream, which entitles us to 50% of all distributions paid by Crestwood Midstream in excess of its initial quarterly distribution of $0.37 per common unit. See Note 13 for additional information.
	Description of Business
	The Company provides gathering, processing, storage and transportation solutions to customers in the crude oil, natural gas liquids (“NGLs”) and natural gas sectors of the energy industry. The Company's financial statements reflect three operating and reporting segments: (i) gathering and processing; (ii) NGL and crude services; and (iii) storage and transportation.
	The Company's gathering and processing (G&P) operations provide natural gas gathering, processing, treating, compression and transportation services to producers in unconventional shale plays in West Virginia, Wyoming, Texas, Arkansas, New Mexico and Louisiana. The consolidated assets reflected in this segment include rich gas gathering systems and processing plants in the Marcellus Shale, Niobrara Powder River Basin, Barnett Shale, Granite Wash, and Avalon Shale plays, and dry gas gathering systems in the Barnett Shale, Fayetteville Shale, and Haynesville Shale plays.
	The Company's NGL and crude services operations provide NGL marketing, supply and logistics services to producers, refiners, petrochemical companies, marketers, and others customers. The consolidated assets reflected in this segment primarily include a crude oil rail loading and storage terminal located in North Dakota (the COLT Hub), the West Coast operations, a fleet of over-the-road truck and rail transports, an NGL storage facility in New York (the Bath storage facility),
	and a solution-mining and salt production company in New York (US Salt). In the quarter ended September 30, 2013, the Company moved its US Salt operations and its Bath storage facility operations to the NGL and crude services segment from the storage and transportation segment.
	The Company's storage and transportation operations provide natural gas storage and transportation services to third parties. The consolidated assets reflected in this segment primarily include natural gas storage facilities in New York and Texas (the Stagecoach, Thomas Corners, Steuben, Seneca Lake and Tres Palacios storage facilities), and natural gas transmission facilities in New York and Pennsylvania (the North-South Facilities, the MARC I Pipeline, and the East Pipeline).
	The Company owns and operates the Tres Palacios natural gas storage facility, a fractionation facility on the West Coast and an NGL supply and logistics business. All other consolidated assets of the Company are owned by or through Crestwood Midstream.
	Basis of Presentation
	These financial statements were originally the financial statements of Legacy CMLP GP, prior to being acquired by the Company on June 19, 2013 as discussed above. The Company’s acquisition of Legacy CMLP GP was accounted for as a reverse acquisition under the purchase method of accounting in accordance with The Financial Accounting Standards Board ("FASB") Accounting Standard Codification Subtopic 805 - Business Combinations. The accounting for a reverse acquisition results in the legal acquiree (Legacy CMLP GP) being the acquiror for accounting purposes. Although Legacy CMLP GP was the surviving entity for accounting purposes, the Company was the surviving entity for legal purposes; consequently, the name on these financial statements was changed from Crestwood Gas Services GP, LLC to Crestwood Equity Partners LP.
	On June 18, 2013, the Company changed its fiscal year-end from September 30 to December 31 to adopt the fiscal year of Legacy CMLP GP.
	The financial information contained herein as of September 30, 2013, and for the three-month and nine-month periods ended September 30, 2013 and 2012, is unaudited. The Company believes this information has been prepared in accordance with accounting principles generally accepted in the United States for interim financial information and Article 10 of Regulation S-X. The Company also believes this information includes all adjustments (consisting only of normal recurring adjustments) necessary to present fairly the financial position, results of operations and cash flows for the periods then ended.
	The accompanying consolidated financial statements should be read in conjunction with the Form 10-K as filed with the Securities and Exchange Commission ("SEC") for the fiscal year ended September 30, 2012 as well as the Form 8-K/A filed August 5, 2013, containing consolidated financial statements related to Legacy CMLP GP.
	The accompanying consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries, including among others Inergy Partners, LLC (“Inergy Partners”), Tres Palacios Gas Storage LLC (“TPGS”), IPCH Acquisition Corp. (“IPCHA”), CEQP Finance Corp. (formerly Inergy Finance Corp.), Inergy Operations, LLC, Crestwood Midstream GP LLC (formerly known as NRGM GP, LLC) and Legacy CMLP GP. The accompanying consolidated financial statements also include the accounts of Inergy Midstream and Legacy Crestwood and their consolidated subsidiaries.
	All significant intercompany transactions and balances have been eliminated in consolidation.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2013
Text Block [Abstract]	'
Summary of Significant Accounting Policies	'
	Summary of Significant Accounting Policies
	Financial Instruments and Price Risk Management
	The Company utilizes certain derivative financial instruments to (i) manage its 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 adequate physical supply of commodity will be available; and (iii) manage its exposure to the interest rate risk associated with fixed and variable rate borrowings. The Company records all derivative instruments on the balance sheet as either assets or liabilities measured at fair value. Changes in the fair value of these derivative financial instruments are recorded either through current earnings or as other comprehensive income, depending on the type of transaction.
	The Company is periodically party to certain commodity derivative financial instruments that are designated as hedges of selected inventory positions. Certain of these instruments may be designated as fair value hedges for accounting purposes. The Company is also periodically party to certain interest rate swap agreements designed to manage interest rate risk exposure. The Company’s overall objective for entering into hedges is to manage its exposure to fluctuations in commodity prices and changes in the fair market value of its inventories and fixed and variable rate borrowings. The commodity derivatives are recorded at fair value on the balance sheets as price risk management assets or liabilities and the related change in fair value is recorded to earnings in the current period as cost of product/services sold.
	The Company had no derivatives identified as fair value hedges for accounting purposes in the three-month and nine-month periods ended September 30, 2013 and 2012.
	The Company also enters into derivative financial instruments that may qualify as cash flow hedges, which hedge the exposure of variability in expected future cash flows predominantly attributable to variable interest payments. These derivatives are recorded on the balance sheet at fair value as other assets or other long-term liabilities. The effective portion of the gain or loss on these cash flow hedges is recorded in other comprehensive income in partner's capital and reclassified into earnings in the same period in which the hedge transaction affects earnings. In certain situations under the rules, the ineffective portion of the gain or loss is recognized as cost of product sold/services sold or interest expense in the current period. The Company did not have any derivatives designated as cash flow hedges in the three-month and nine-month periods ended September 30, 2013 and 2012.
	The Company’s policy is to offset fair value amounts of derivative instruments and cash collateral paid or received with the same counterparty under a master netting arrangement.
	The cash flow impact of derivative financial instruments is reflected as cash flows from operating activities in the consolidated statements of cash flows.
	Revenue Recognition
	The Company's gathering and processing operations gather, process, treat, compress, transport and sell natural gas pursuant to fixed-fee and percent-of-proceeds contracts. For fixed-fee contracts, the Company recognizes revenues based on the volume of natural gas gathered, processed and treated or compressed. For percent-of-proceeds contracts, the Company recognizes revenues based on the value of products sold to third parties. The Company recognizes revenues for these services and products when all of the following criteria are met:
	• services have been rendered or products delivered;
	• persuasive evidence of an exchange arrangement exists;
	• the price for services is fixed or determinable; and
	• collectability is reasonably assured.
	Sales of NGLs and salt are recognized at the time product is shipped or delivered to the customer depending on the sales terms. NGL processing and fractionation fees are recognized upon delivery of the product. Revenues from the COLT Hub are recognized when the contractual services are provided, such as loading of customer rail cars. Revenues from storage and transportation contracts are recognized during the period in which the storage and transportation services are provided, such as providing storage and transportation services during the period a firm service contract is in place.
	Credit Risk and Concentrations
	Inherent in the Company's contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. The Company takes an active role in managing credit risk and has established control procedures, which are reviewed on an ongoing basis. The Company attempts 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.
	Two customers, Quicksilver Resources Inc. (“Quicksilver”) and Antero Resources Appalachian Corporation (“Antero”), accounted for approximately 44% and 13% of the Company's total revenue for the three months ended September 30, 2012, respectively. No customers accounted for 10% or more of the Company's total revenue in the three months ended September 30, 2013. Quicksilver accounted for approximately 12% and 50% of the Company's total revenue for the nine months ended September 30, 2013 and 2012, respectively.  No other customer accounted for 10% or more of the Company's total revenue in those periods. All Quicksilver and Antero revenues are captured in the gathering and processing segment.
	At December 31, 2012, Quicksilver and Antero accounted for approximately 48% and 14% of the Company's consolidated accounts receivable, respectively. No customer accounted for 10% or more of the Company's consolidated accounts receivable at September 30, 2013.
	Use of Estimates
	The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the periods presented. Actual results could differ from those estimates.
	Inventory
	Inventory for NGL and crude services operations, which mainly consist of NGLs, are stated at the lower of cost or market and are computed using the average cost method. Inventory for storage and transportation operations are stated at the lower of cost or market and are computed predominantly using the average cost method. Legacy CMLP GP had no inventory at December 31, 2012.
	Shipping and Handling Costs
	Shipping and handling costs are recorded as part of cost of product/services sold at the time product is shipped or delivered to the customer.
	Property, Plant and Equipment
	Property, plant and equipment is recorded at its original cost of construction or, upon acquisition, at fair value of the assets acquired. For assets the Company constructs, it capitalizes direct costs, such as labor and materials, and indirect costs, such as overhead and interest. The Company capitalizes major units of property replacements or improvements and expenses minor items. Depreciation is computed by the straight-line method over the estimated useful lives of the assets, as follows:
		Years
	Gathering systems	20
	Processing plants and compression facilities	20 – 25
	Buildings, rights-of-way, easements and storage rights	20 – 70
	Office furniture and equipment	5 – 10
	Vehicles	5
	Pipelines	20
	Base gas	10
	Salt deposits are depleted utilizing the unit of production method.
	Identifiable Intangible Assets
	The Company has recorded certain identifiable intangible assets, including customer accounts, covenants not to compete, trademarks, deferred financing costs and gas gathering, compression and processing contracts. Customer accounts, covenants not compete and trademarks have arisen from acquisitions. Deferred financing costs represent financing costs incurred in obtaining financing and are being amortized over the term of the related debt using the effective interest method. The Company recognizes acquired intangible asset 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.
	Customer accounts, covenants not to compete and trademarks are generally amortized on a straight-line basis over their estimated economic lives, typically 10 years, 2 - 9 years and 5 - 10 years, respectively. The customer accounts associated with the NGL and crude services segment and the gas gathering, compression and processing contracts are generally amortized based on the projected cash flows associated with the contracts, typically 5 - 20 years.
	Goodwill
	Goodwill is recognized for various acquisitions as the excess of the cost of the acquisitions over the fair value of the related net assets at the date of acquisition. Goodwill is subject to at least an annual assessment for impairment by applying a fair-value-based test.
	The Company completed its annual impairment test for each of its reporting units and determined that no impairment existed as of December 31, 2012. During the three months ended September 30, 2013, the Company recorded an impairment of goodwill of approximately $4.1 million on its Haynesville/Bossier Shale system as a result of a decrease in anticipated revenues to be generated from those operations due primarily to the Company's inability to renew and extend a significant revenue contract that expired in mid-2013.
	Investment in Unconsolidated Affiliate
	The Company applies the equity method of accounting where it can exert significant influence over, but does not control or direct, the policies, decisions or activities of the entity. The Company uses the cost method of accounting where it is unable to exert significant influence over the entity. The FASB's accounting standards related to equity method investments and joint ventures requires entities to periodically review their equity method investments to determine whether current events or circumstances indicate that the carrying value of the equity method investment may be impaired. The Company evaluates its equity method investment for impairment when there are indicators of impairment. If indicators suggest impairment, the Company will perform an impairment test to assess whether an adjustment is necessary. The impairment test considers whether the fair value of the Company's equity method investment declined and if any such decline is other than temporary. If a decline in fair value is determined to be other than temporary, the investment's carrying value is written down to fair value.
	Income Taxes
	The Company is a publicly-traded master limited partnership. Partnerships are generally not subject to federal income tax, although publicly-traded partnerships are treated as corporations for federal income tax purposes and therefore are subject to federal income tax, unless the partnership generates at least 90% of its gross income from qualifying sources. If the qualifying income requirement is satisfied, the publicly-traded partnership will be treated as a partnership for federal income tax purposes. The earnings of the Company and its limited liability subsidiaries are included in the federal and state income tax returns of the individual members or partners. However, legislation in certain states allows for taxation of partnerships, and as such, certain state taxes for the Company have been included in the 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. The Company is 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 differences are expected to reverse.
	The Company is responsible for its portion of the Texas Margin tax that is included in Crestwood Holdings' consolidated Texas franchise tax return. The Company's current tax liability will be assessed based on 0.7% of the gross revenue apportioned to Texas. The margin tax qualifies as an income tax under GAAP, which requires the Company 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.
	Sales Tax
	The Company accounts for the collection and remittance of sales tax on a net tax basis. As a result, these amounts are not reflected in the consolidated statements of operations.
	Income Per Unit
	The Company calculates basic net income per limited partner unit by utilizing the two class method. Diluted net income per limited partner unit is computed by dividing net income attributable to the limited partners by the weighted-average number of units outstanding and the effect of dilutive units granted in the Company's acquisition of Legacy CMLP GP. Net income attributable to the limited partners is determined by first allocating to the Company the earnings from the IDR interests from Crestwood Midstream (or, prior to the Crestwood Merger, the general partner and IDR interests of Inergy Midstream and Legacy CMLP) with the remaining earnings allocated according to the capital accounts. The weighted average number of units outstanding is calculated based on the presumption that the common and subordinated units issued to acquire Legacy CMLP GP (the accounting predecessor) were outstanding for the entire period prior to the June 19, 2013 acquisition. On the date of the acquisition, all of the Company's limited partner units are considered outstanding.
	Accrued Additions to Property, Plant and Equipment
	The Company has accrued for property, plant and equipment, including certain construction work in process relating to construction efforts on various growth projects. At September 30, 2013 and December 31, 2012, the Company had accrued $47.4 million and $9.2 million relating to property, plant and equipment classified as accrued expenses on the consolidated balance sheets.
	Asset Retirement Obligations
	An asset retirement obligation ("ARO") is an estimated liability for the cost to retire a tangible asset. The Company records a liability for legal or contractual obligations to retire its long-lived assets associated with right-of-way contracts it holds and its facilities whether owned or leased. The Company records 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 value of the liability as a result of the passage of time, which the Company records as depreciation, amortization and accretion expense on its consolidated statements of operations. The fair value of certain AROs could not be determined as settlement dates (or range of dates) associated with these assets were not estimable. The net AROs were $14.6 million and $14.0 million at September 30, 2013 and December 31, 2012, respectively, and are included in other long-term liabilities on the consolidated balance sheets.
	Environmental Costs and Other Contingencies
	The Company recognizes liabilities for environmental and other contingencies when it has 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, the Company accrues 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 the range is accrued.
	The Company records liabilities for environmental contingencies at their undiscounted amounts on its 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 the Company's 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. The Company capitalizes costs that benefit future periods and recognize a current period charge in operation and maintenance expense when clean-up efforts do not benefit future periods.
	The Company evaluates potential recoveries of amounts from third parties, including insurance coverage, separately from its liability. Recovery is evaluated based on the solvency of the third party, among other factors. When recovery is assured, the Company records and reports an asset separately from the associated liability on its consolidated balance sheet.
	Accounting for Unit-Based Compensation
	Unit-based compensation awards are valued at the closing market price of our 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. The Company generally recognizes the expense associated with the award over the vesting period. At the time of issuance of phantom units, management of the General Partner determines whether they will be settled in cash or settled in common units. Unit-based compensation awards at Inergy Midstream and Legacy Crestwood are fully reflected in these financial statements and are accounted for in the manner described above.
	The amount of compensation expense recorded by the Company was $5.6 million and $0.5 million during the three months ended September 30, 2013 and 2012, respectively, and $7.6 million and $1.5 million during the nine months ended September 30, 2013 and 2012, respectively.
Segment Information
There are certain accounting requirements that establish standards for reporting information about operating segments, as well as related disclosures about products and services, geographic areas and major customers. Further, they define operating segments as components of an enterprise for which separate financial information is available that is evaluated regularly by the chief operating decision maker in deciding how to allocate resources and assess performance. In determining its operating segments, the Company examined the way it organizes its business internally for making operating decisions and assessing business performance. See Note 10 for disclosures related to the Company’s three operating and reporting segments.
Fair Value
Cash and Cash Equivalents, Accounts Receivable and Accounts Payable
As of September 30, 2013 and December 31, 2012, the carrying amounts of cash and cash equivalents, accounts receivable (net of allowance for doubtful accounts) and accounts payable represent fair value due to their liquid and short-term nature.
Credit Facilities
The fair value of the Company's credit agreement and all of its credit facilities approximates their carrying amounts as of September 30, 2013 and December 31, 2012 due primarily to the variable nature of the interest rates of the instruments.
Senior Notes
The Company estimates the fair value of its senior notes primarily based on quoted market prices for the same or similar issuances. This valuation methodology is considered level 2 in the fair value hierarchy. The following table reflects the carrying value and fair value of the senior notes (in millions):
	September 30, 2013				December 31, 2012
	Carrying Amount		Fair		Carrying Amount		Fair
			Value				Value
CEQP senior unsecured notes	$	11.5	$	11.5	$	—	$	—
Legacy CMLP senior unsecured notes	$	351.3	$	369.3	$	351.5	$	365.9
NRGM senior unsecured notes	$	500	$	497.8	$	—	$	—
See Note 6 for a discussion of the Company's assets and liabilities recorded at fair value on the balance sheet.
Recently Issued Accounting Pronouncements
On December 16, 2011, the FASB issued ASU No. 2011-11, “Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities.” This ASU requires disclosures to provide information to help reconcile differences in the offsetting requirements under U.S. Generally Accepted Accounting Principles and International Financial Reporting Standards. The disclosure requirements of this ASU mandate that entities disclose both gross and net information about financial instruments and transactions eligible for offset in the statement of financial position as well as instruments and transactions subject to an enforceable master netting arrangement or similar agreement. ASU No. 2011-11 also requires disclosure of collateral received and posted in connection with master netting arrangements or similar arrangements. The scope of this ASU includes derivative contracts, repurchase agreements, and securities borrowing and lending arrangements. Entities are required to apply the amendments of ASU No. 2011-11 for annual reporting periods beginning on or after January 1, 2013, and interim periods within those annual periods. All disclosures provided by those amendments are required to be provided retrospectively for all comparative periods presented. The Company adopted the effects of ASU No. 2011-11 on January 1, 2013.
On February 5, 2013, the FASB issued ASU No. 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income.” This ASU amends and clarifies the disclosure requirements prescribed in ASU No. 2011-05, “Comprehensive Income (Topic 220): Presentation of Comprehensive Income.” ASU No. 2013-02 requires that entities present information about reclassification adjustments from accumulated other comprehensive income in their annual financial statements in a single note or on the face of the financial statements. Public entities will also have to provide this information in their interim financial statements. Specifically, entities must present, either in a single note or parenthetically on the face of the financial statements, the effect of significant amounts reclassified from each component of accumulated other comprehensive income based on its source and the income statement line items affected by the reclassification. If a component is not required to be reclassified to net income in its entirety, entities would instead cross reference to the related footnote for additional information.  The Company adopted the requirements of ASU No. 2013-02 on January 1, 2013 and presented the required information in a single note.

Certain_Balance_Sheet_Informat

Certain Balance Sheet Information	9 Months Ended
	Sep. 30, 2013
Balance Sheet Related Disclosures [Abstract]	'
Certain Balance Sheet Information	'
	Certain Balance Sheet Information
	Inventory consisted of the following at September 30, 2013 and December 31, 2012, respectively (in millions):
		September 30,		December 31,
		2013		2012
	NGLs	$	88.8	$	—
	Parts, supplies and other	6.9		—
	Total inventory	$	95.7	$	—
	Property, plant and equipment consisted of the following at September 30, 2013 and December 31, 2012, respectively (in millions):
		September 30,		December 31,
		2013		2012
	Gathering systems	$	662.5	$	582.3
	Processing plants and compression facilities	544.5		485.4
	Plant equipment	522.3		—
	Buildings, rights-of-way and easements	75.2		66.4
	Land and storage rights	755.7		4.1
	Pipelines	661		—
	Vehicles	32.9		0.3
	Construction in process	246.6		56
	Base gas	97.9		—
	Salt deposits	120.5		—
	Office furniture and equipment	8.8		2.9
		3,727.90		1,197.40
	Less: accumulated depreciation	167.8		95
	Total property, plant and equipment, net	$	3,560.10	$	1,102.40
	The Company had capital lease assets of $11.5 million and $11.8 million included in property, plant and equipment at September 30, 2013 and December 31, 2012, respectively.
	Intangible assets consisted of the following at September 30, 2013 and December 31, 2012, respectively (in millions):
		September 30,		December 31,
		2013		2012
	Customer accounts	$	231	$	—
	Covenants not to compete	7		—
	Gas gathering, compression and processing contracts	750.1		813
	Acquired storage contracts	43.5		—
	Trademarks	33.5		—
	Deferred financing and other costs	33.8		32.2
		1,098.90		845.2
	Less: accumulated amortization	84.8		49.9
	Total intangible assets, net	$	1,014.10	$	795.3

Business_Acquisitions

Business Acquisitions	9 Months Ended
	Sep. 30, 2013
Business Combinations [Abstract]	'
Business Acquisitions	'
	Business Acquisitions
	Jackalope Acquisition
	On June 24, 2013, Crestwood Niobrara LLC (“Crestwood Niobrara”) entered into an agreement with RKI Exploration and Production LLC (“RKI”) to purchase RKI's 50% interest in Jackalope Gas Gathering Services, L.L.C. ("Jackalope"), which owns a rich gas gathering system located in the Powder River Basin Niobrara play, for approximately $107.5 million. We completed the acquisition on July 19, 2013. Crestwood Niobrara financed the Jackalope acquisition through (i) a capital contribution of approximately $26.9 million by Legacy CMLP, which Legacy CMLP funded with borrowings under its credit facility, and (ii) the issuance of approximately $80.6 million of preferred securities to a subsidiary of General Electric Capital Corporation and GE Structured Finance, Inc. (collectively, “GE EFS”).
	Crestwood Niobrara expects to fund up to 75% of its future capital contributions to Jackalope through the issuance of additional preferred securities to GE EFS (not to exceed $69.4 million in the aggregate), with the remaining portion of such capital contributions to be funded by CMLP capital contributions. CMLP serves as the managing member of Crestwood Niobrara and, subject to certain restrictions, CMLP has the right to redeem GE EFS's preferred securities with cash or CMLP common units.
	CEQP Reverse Acquisition
	As described in Note 1, the Company's acquisition of Legacy CMLP GP was accounted for as a reverse acquisition under the purchase method of accounting in accordance with FASB Accounting Standard Codification Subtopic 805 - Business Combinations. This accounting treatment requires the accounting acquiree (CEQP) to have its assets and liabilities stated at fair value as well as any other purchase accounting adjustments as of the date of the acquisition, June 19, 2013. The fair value of CEQP was calculated based on the consolidated enterprise value of CEQP as of June 19, 2013. This consolidated enterprise value was based on the stock prices of CEQP and NRGM, the value of the outstanding senior notes based on quoted market prices for same or similar issuances and the value of the outstanding floating rate debt. The preliminary purchase allocation is subject to material change pending the completion of the valuation of assets acquired and liabilities assumed.
	The following table summarizes the estimated fair values of the assets acquired and liabilities assumed at the merger date (in millions):
		June 19,		Preliminary Estimate (a)			Adjustment Based on Revised Valuation Report
		2013
	Current assets	$	222.7	$	222.7		$	—
	Property, plant and equipment	2,259.70		2,554.90			(295.2		)
	Intangible assets	315		273			42
	Other assets	12.7		51.2			(38.5		)
	Total identifiable assets acquired	2,810.10		3,101.80			(291.7		)
	Current liabilities	208.9		205.5			3.4
	Long-term debt	1,079.30		1,079.30			—
	Other long-term liabilities	213.1		43.9			169.2
	Total liabilities assumed	1,501.30		1,328.70			172.6
	Net identifiable assets acquired	1,308.80		1,773.10			(464.3		)
	Goodwill	2,564.40		2,100.10			464.3
	Net assets acquired	$	3,873.20	$	3,873.20		$	—
	(a)    Provisional amount recorded as of June 30, 2013.
	The changes from the preliminary estimate were based on additional valuation information obtained on certain of our storage and transportation assets and obligations, primarily related to our Tres Palacios storage operations.  These revised estimates continue to be preliminary and are subject to material change pending the final valuation of these assets and liabilities.
	The adjustments to the purchase price allocation did not materially impact the statements of operations for the quarters ended June 30, 2013 or September 30, 2013.
	The $2,564.4 million of goodwill is reflected in the Company's NGL and crude services segment and storage and transportation segment. Goodwill recognized relates primarily to synergies and new expansion opportunities expected upon completion of the integration of CEQP and Legacy CMLP GP.  Based on the preliminary purchase price allocation, amortization expenses relative to the intangible assets acquired are expected to be $32.5 million, $51.2 million, $43.7 million, $35.8 million and $31.5 million for each of the years ended December 31, 2013 through December 31, 2017.
	The following table represents the pro forma consolidated statements of operations as if the reverse acquisition had been included in the consolidated results of the Company for the three-month period ended September 30, 2012 and for the full nine-month periods ended September 30, 2013 and 2012 (in millions, except per unit information):
		Pro Forma Consolidated
		Statement of Operations
		(Unaudited)
		Three Months Ended		Nine Months Ended
		September 30,		September 30,
		2012 (a)		2013			2012 (a)
	Revenues	$	333.7	$	1,339.90		$	1,026.40
	Net income (loss)	$	73.2	$	(34.2	)	$	105.1
	Net income (loss) per limited partner unit:
	Basic	$	1.9	$	(0.33	)	$	2.42
	Diluted	$	1.69	$	(0.33	)	$	2.15
	(a)	The three-month and nine-month periods ended September 30, 2012 have also been adjusted to reflect the contribution of the Company's retail operations to Suburban Propane Partners on August 1, 2012 as if that contribution had been removed from the consolidated results of operations at the beginning of each period presented.
	These amounts have been calculated after applying the Company's accounting policies and adjusting the results of the reverse acquisition to reflect the depreciation and amortization that would have been charged assuming the preliminary fair value adjustments to property, plant and equipment and intangible assets had been made at the beginning of the respective reporting period. The purchase price allocation for the reverse acquisition has been prepared on a preliminary basis pending final asset valuation and asset rationalization, and changes are expected when additional information becomes available. Accordingly, the purchase accounting adjustments made in connection with the development of the unaudited pro forma are preliminary and subject to change.

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2013
Fair Value, Assets and Liabilities Measured on Recurring Basis [Abstract]	'
Fair Value Measurements	'
	Fair Value Measurements
	FASB Accounting Standards Codification Subtopic 820-10 (“820-10”) establishes a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (level 1 measurement) and the lowest priority to unobservable inputs (level 3 measurement). The three levels of the fair value hierarchy are as follows:
	•	Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of financial instruments such as exchange-traded derivatives, listed equities and US government treasury securities.
	•	Level 2—Pricing inputs are other than quoted prices in active markets included in level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives such as over the counter (“OTC”) forwards, options and physical exchanges.
	•	Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.
	As of September 30, 2013, the Company held certain assets and liabilities that are required to be measured at fair value on a recurring basis. These included the Company’s derivative instruments related to heating oil, crude oil, NGLs and interest rates. The Company’s derivative instruments consist of forwards, swaps, futures, physical exchanges and options.
	Certain of the Company’s derivative instruments are traded on the NYMEX. These instruments have been categorized as level 1.
	The Company’s 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.
	The Company’s 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.
	The assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company's 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 the Company's assets and liabilities that were accounted for at fair value on a recurring basis at September 30, 2013 (in millions):
		30-Sep-13
		Fair Value of Derivatives
		Level 1		Level 2		Level 3		Total		Designated		Not		Netting			Total
										as Hedges		Designated		Agreements(a)
												as Hedges
	Assets
	Assets from price risk management	$	0.3	$	35.9	$	—	$	36.2	$	—	$	36.2	$	(12.5	)	$	23.7
	SPH units	6.6		—		—		6.6		—		6.6		—			6.6
	Total assets at fair value	$	6.9	$	35.9	$	—	$	42.8	$	—	$	42.8	$	(12.5	)	$	30.3
	Liabilities
	Liabilities from price risk management	$	0.3	$	29.7	$	—	$	30	$	—	$	30	$	1.9		$	31.9
	Interest rate swaps	—		4.8		—		4.8		—		4.8		—			4.8
	Total liabilities at fair value	$	0.3	$	34.5	$	—	$	34.8	$	—	$	34.8	$	1.9		$	36.7
	(a)	Amounts represent the impact of legally enforceable master netting agreements that allow the Company to settle positive and negative positions as well as cash collateral held or placed with the same counterparties.
	The Company had no assets or liabilities recorded at fair value at December 31, 2012.

Risk_Management

Risk Management	9 Months Ended
	Sep. 30, 2013
Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]	'
Risk Management	'
	Risk Management
	The Company is exposed to certain market risks related to its ongoing business operations. These risks include exposure to changing commodity prices as well as fluctuations in interest rates. The Company utilizes derivative instruments to manage its exposure to fluctuations in commodity prices, which is discussed below. The Company also periodically utilizes derivative instruments to manage its exposure to fluctuations in interest rates, which is discussed in Note 7. Additional information related to derivatives is provided in Note 2 and Note 6.
	Commodity Derivative Instruments and Price Risk Management
	Risk Management Activities
	The Company sells NGLs to energy related businesses and may use a variety of financial and other instruments including forward contracts involving physical delivery of NGLs. The Company will enter into offsetting positions to economically hedge against the exposure its customer contracts create, however does not designate these instruments as hedging instruments for accounting purposes. These instruments are marked to market with the changes in the market value reflected in cost of product/services sold. The Company attempts to balance its 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 cost of product/services sold related to these instruments.
	Fair Value Hedging Activity
	The Company will enter into derivative instruments to hedge its exposure to fluctuating commodity prices that results from maintaining its NGL inventory. The Company may choose to designate these instruments as fair value hedges for accounting purposes. This accounting treatment requires the fair value changes in both the derivative instruments and the hedged inventory to be recorded in cost of product/services sold.
	A significant amount of inventory held in bulk storage facilities is hedged as it is not expected to be sold in the immediate future and is therefore exposed to fluctuations in commodity prices.
	The Company did not have any derivative instruments designated as fair value hedges for accounting purposes during the three-month and nine-month periods ended September 30, 2013 and September 30, 2012.
	Commodity Price and Credit Risk
	Notional Amounts and Terms
	The notional amounts and terms of the Company’s derivative financial instruments include the following at September 30, 2013 and December 31, 2012, respectively (in millions):
		30-Sep-13		31-Dec-12
		Fixed Price	Fixed Price	Fixed Price	Fixed Price
		Payor	Receiver	Payor	Receiver
	Propane, crude and heating oil (barrels)	7.2	8.8	—	—
	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 the Company’s monetary exposure to market or credit risks.
	All contracts subject to price risk had a maturity of thirty-four months or less; however, 95.9% of the contracts expire within twelve months.
	Credit Risk
	Inherent in the Company's contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. The Company takes an active role in managing credit risk and has established control procedures, which are reviewed on an ongoing basis. The Company attempts 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 assets from price risk management activities as of September 30, 2013 were energy marketers and propane retailers, resellers and dealers. There were no activities associated with assets from price risk management at December 31, 2012.
	Certain of the Company's derivative instruments have credit limits that require the Company 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 the Company's established credit limit with the respective counterparty. If the Company's credit rating were to change, the counterparties could require the Company 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 the Company's 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 are in a liability position on September 30, 2013, is $12.1 million for which the Company has posted $1.5 million of collateral in the normal course of business. The Company has posted $5.2 million of NYMEX margin deposits in the normal course of business. The Company has received collateral of $10.2 million in the normal course of business. All collateral amounts have been netted against the asset or liability with the respective counterparty.

LongTerm_Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2013
Text Block [Abstract]	'
Long-Term Debt	'
	Long-Term Debt
	Long-term debt consisted of the following at September 30, 2013 and December 31, 2012, respectively (in millions):
		September 30,		December 31,
		2013		2012
	CEQP credit agreement	$	376.2	$	—
	CEQP senior notes	11.5		—
	CEQP obligations under noncompetition agreements and notes to former owners of businesses acquired	2.9		—
	Legacy CMLP credit facility	356.2		206.7
	Legacy CMLP senior notes	350		350
	Premium on Legacy CMLP senior notes	1.3		1.5
	CMM credit facility	191.9		127
	NRGM credit facility	37		—
	NRGM senior notes	500		—
	Fair value adjustment of NRGM senior notes	4.8		—
	Total debt	1,831.80		685.2
	Less: current portion	4.4		—
	Total long-term debt	$	1,827.40	$	685.2
	CEQP and its subsidiaries do not provide credit support or guarantee any amounts outstanding under the credit facilities or notes of Crestwood Midstream. Crestwood Midstream and its subsidiaries do not provide credit support or guarantee any amounts outstanding under CEQP’s credit facility or senior notes.
	CEQP Credit Facility
	The Company utilizes a secured credit facility (the "CEQP Credit Facility") with an aggregate revolving loan facility of $550 million to fund working capital requirements and as a source of capital to fund capital expenditures and acquisitions. All borrowings under the CEQP Credit Facility are generally secured by substantially all of the Company's assets and the equity interests in all of the Company's wholly owned subsidiaries, and loans thereunder bear interest, at the Company's option, subject to certain limitations, at a rate equal to the following:
	•	the Alternate Base Rate, which is defined as the higher of (i) the federal funds rate plus 0.50%; (ii) JP Morgan's prime rate; or (iii) the Adjusted LIBO Rate plus 1%; plus a margin varying from 0.75% to 2.00%; or
	•	the Adjusted LIBO Rate, which is defined as the LIBO Rate plus a margin varying from 1.75% to 3.00%.
	At September 30, 2013, the balance outstanding under the CEQP Credit Facility was $376.2 million. The interest rates of the CEQP Credit Facility are based on prime rate and LIBOR plus the applicable spreads, resulting in interest rates which were between 2.69% and 4.75% at September 30, 2013. Availability under the CEQP Credit Facility amounted to $122.6 million at September 30, 2013. Outstanding standby letters of credit under the credit facility amounted to $51.2 million at September 30, 2013.
	The credit agreement governing the CEQP Credit Facility contains various covenants and restrictive provisions that limit its ability to, among other things: incur additional debt; make distributions on or redeem or repurchase units; make certain investments and acquisitions; incur or permit certain liens to exist; enter into certain types of transactions with affiliates; merge, consolidate or amalgamate with another company; and transfer or otherwise dispose of assets.
	The CEQP Credit Facility contains the following financial covenants:
	•	the ratio of CEQP's total funded debt (as defined in the credit agreement) to consolidated EBITDA (as defined in the credit agreement) for the four fiscal quarters most recently ended must be no greater than 4.75 to 1.0; and
	•	the ratio of CEQP's consolidated EBITDA to consolidated interest expense (as defined in the credit agreement), for the four fiscal quarters then most recently ended, must not be less than 2.50 to 1.0.
	At September 30, 2013, the total funded debt to consolidated EBITDA was approximately 4.3 to 1.0 and consolidated EBITDA to consolidated interest expense was approximately 10.2 to 1.0.
	On May 23, 2013, the Company obtained from its lenders certain waivers and consents necessary to consummate the transactions that resulted in Crestwood Holdings' acquisition of the Company's general partner and the Company's acquisition of the general partner of Legacy Crestwood. The Company also amended its credit agreement to, among other things, (i) require the Company to prepay up to $300 million in aggregate principal amount of borrowings outstanding under the CEQP Credit Facility with net proceeds received by the Company or its subsidiaries from asset dispositions or insurance proceeds (“Net Proceeds”), (ii) automatically reduce the lenders' revolving loan commitments by an amount equal to the Net Proceeds, and (iii) permit the sale of assets from the Company to its subsidiaries and to Inergy Midstream and its subsidiaries.
	On August 28, 2013, the Company entered into that certain Consent, Waiver and Amendment No. 6 (the “Consent and Amendment”) that amends the definition of “Consolidated EBITDA” in the CEQP credit agreement to account for (i) the Company’s distribution on June 19, 2013 of NRGM common units to the Company’s unitholders and (ii) distributions received by the Company from Inergy Midstream and Legacy CMLP before and after the closing of the Crestwood Merger. The Consent and Amendment also changed the Company’s fiscal year-end from September 30 to December 31.
	The Company has entered into six interest rate swaps that mature in 2016 to reduce our exposure to variable interest payments due under the CEQP Credit Facility. These swap agreements require the Company to pay the counterparty an amount based on fixed rates from 0.84% to 2.52% due quarterly on an aggregate notional amount of $225.0 million. In exchange, the counterparty is required to make quarterly floating interest rate payments on the same date to the Company based on the three-month LIBOR applied to the same aggregate notional amount of $225.0 million.
	CEQP Senior Notes
	At September 30, 2013, the Company had $11.5 million in outstanding senior notes, the majority of which mature on October 1, 2018 and have a coupon rate of 7%. The outstanding senior notes do not contain any financial covenants.
	Retirement of Credit Facilities
	Contemporaneously with the closing of the Crestwood Merger on October 7, 2013, Crestwood Midstream entered into a new five-year $1 billion senior secured revolving credit facility (the "Crestwood Midstream Revolver") and immediately thereafter repaid and retired the Legacy CMLP Credit Facility, the CMM Credit Facility, and the NRGM Credit Facility with borrowings under the Crestwood Midstream Revolver. See Note 13 for additional information.
	Legacy CMLP Credit Facility
	Borrowings under the Legacy CMLP Credit Facility, repaid and retired on October 7, 2013, bear interest at LIBOR plus an applicable margin or a base rate as defined in the CMLP credit agreement. Under the terms of the credit facility, the applicable margin under LIBOR borrowings was 2.8% and 2.5% at September 30, 2013 and December 31, 2012, respectively. The weighted-average interest rate as of September 30, 2013 and December 31, 2012 was 3.0% and 2.8%, respectively. At September 30, 2013 and December 31, 2012, the balance outstanding under the Legacy CMLP Credit Facility was $356.2 million and $206.7 million, respectively.
	Legacy CMLP Senior Notes
	In April 2011, Legacy CMLP and Crestwood Midstream Finance Corporation (“Legacy CMLP Finance” and together with Legacy CMLP, the “Legacy CMLP Issuers”) issued $200 million in a private offering in aggregate principal amount of their 7.75% Senior Notes due 2019 (the “Initial CMLP Notes”). On November 14, 2012, the Legacy CMLP Issuers issued and sold an additional $150 million in a private offering in aggregate principal amount of their 7.75% Senior Notes due 2019 (the “Additional CMLP Notes,” and together with the Initial CMLP Notes, the “Legacy CMLP Notes”). The Legacy CMLP Notes will mature on April 1, 2019, and interest is payable semi-annually in arrears on April 1 and October 1 of each year. Interest payments commenced on October 1, 2011 and April 1, 2013 for the Initial CMLP Notes and the Additional CMLP Notes, respectively, noting that interest payable on the Additional CMLP Notes' April 1, 2013 payment date commenced accruing on October 1, 2012.
	In general, the Legacy CMLP Notes are fully and unconditionally guaranteed, joint and severally, on a senior unsecured basis by Legacy CMLP's subsidiaries (other than Legacy CMLP Finance, Crestwood Niobrara LLC, and CMM and its subsidiaries). The indenture contains 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 indenture; (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 Legacy CMLP or any other guarantor subsidiary, provided it no longer guarantees indebtedness under the Legacy CMLP Credit Facility. Legacy CMLP has no independent assets or operations, and Legacy CMLP Finance is a 100% finance subsidiary of Legacy CMLP.
	The indenture restricts the ability of Legacy CMLP and its subsidiaries to, among other things, sell assets; pay distributions on, redeem or repurchase Legacy CMLP units, 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 Legacy CMLP from its restricted subsidiaries; consolidate, merge or transfer all or substantially all of Legacy CMLP's assets; and, engage in affiliate transactions; create unrestricted subsidiaries. These restrictions are subject to a number of important exceptions and qualifications, and many of these restrictions will terminate when the senior notes are rated investment grade and no default under the indenture has occurred and is continuing.
	CMM Credit Facility
	At September 30, 2013 and December 31, 2012, the balance outstanding under the CMM Credit Facility, repaid and retired on October 7, 2013, was $191.9 million and $127.0 million, respectively. There were no outstanding standby letters of credit under the CMM Credit Facility at September 30, 2013.
	Borrowings under the CMM Credit Facility bear interest at LIBOR plus an applicable margin or base rate, as defined in the credit agreement governing the CMM Credit Facility. Under the terms of the CMM Credit Facility, the applicable margin under LIBOR was 2.8% and 2.5% at September 30, 2013 and December 31, 2012. The weighted-average interest rate as of September 30, 2013 and December 31, 2012 was 3.0% and 2.8%.
	NRGM Credit Facility
	At September 30, 2013, the balance outstanding under the NRGM Credit Facility, repaid and retired on October 7, 2013, was $37.0 million. Outstanding standby letters of credit under the NRGM Credit Facility amounted to $2.0 million at September 30, 2013.
	NRGM Senior Notes
	At September 30, 2013, the balance outstanding on the Inergy Midstream 6.0% Senior Notes due 2020 (the “NRGM Notes”) was $500.0 million. The Company recorded a $4.8 million adjustment in conjunction with the CEQP reverse acquisition to adjust the debt to fair value. The senior notes will mature on December 15, 2020, and interest is payable semi-annually in arrears on June 15 and December 15 of each year.
	In general, the NRGM Notes are fully and unconditionally guaranteed, joint and severally, on a senior unsecured basis by Inergy Midstream's subsidiaries other than Crestwood Midstream Finance Corp. (formerly known as NRGM Finance Corp., ("Finance Corp.")). The indenture contains 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 indenture; (ii) designation of a guarantor subsidiary as an Unrestricted Subsidiary in accordance with our 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 ours or any other guarantor subsidiary, provided it no longer guarantees indebtedness under the NRGM Credit Facility. Inergy Midstream has no independent assets or operations, and Finance Corp. is a 100% finance subsidiary of Inergy Midstream.
	The indenture restricts the ability of Inergy Midstream and its subsidiaries to, among other things, sell assets; pay distributions on, redeem or repurchase NRGM units, 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 Inergy Midstream from its restricted subsidiaries; consolidate, merge or transfer all or substantially all of Inergy Midstream's assets; and, engage in affiliate transactions; create unrestricted subsidiaries. These restrictions are subject to a number of important exceptions and qualifications, and many of these restrictions will terminate when the senior notes are rated investment grade and no default under the indenture has occurred and is continuing.
	On May 14, 2013, Inergy Midstream commenced a consent solicitation for the purpose of amending the indenture to ensure that the consummation of the Crestwood Merger would not constitute a “Change of Control” thereunder, which would have entitled the note holders to require Inergy Midstream to repurchase the senior notes. The consent solicitation was conditioned on the receipt of consents from holders of record on the record date of a majority in aggregate principal amount of the NRGM Notes. On May 22, 2013, following its receipt of the requisite consents, Inergy Midstream entered into a second supplemental indenture memorializing the requested changes to the indenture. As part of the consent solicitation, consents were delivered and not revoked by holders of approximately $464.5 million in aggregate principal amount (or 92.9%) of the NRGM Notes.

Partners_Capital

Partners' Capital	9 Months Ended
	Sep. 30, 2013
Partners' Capital Account, Distributions [Abstract]	'
Partners' Capital	'
	Partners’ Capital
	Preferred Equity of Subsidiary
	In conjunction with the Jackalope acquisition discussed in Note 4, Crestwood Niobrara issued a preferred interest of approximately $80.6 million to GE EFS. The preferred interest is reflected as noncontrolling interest in our consolidated financial statements.
	During the three and nine months ended September 30, 2013, GE EFS contributed $96.1 million (which consisted of the initial contribution of $80.6 million and additional capital contributions of $15.5 million) to Crestwood Niobrara in exchange for an equivalent number of preferred units. The proceeds from the initial GE EFS contribution were used to purchase the investment in Jackalope and the proceeds from the subsequent contributions were used to fund capital contributions to the Jackalope investment.
	Common Unit Offering
	On March 22, 2013, Legacy CMLP completed a public offering of 4,500,000 common units at a price of $23.90 per common unit ($23.00 per common unit, net of underwriting discounts) providing net proceeds of approximately $103.5 million. Legacy CMLP granted the underwriters a 30 day option to purchase up to 675,000 additional common units if the underwriters sold more than 4,500,000 common units in the offering. The underwriters exercised this option on April 5, 2013, providing net proceeds of approximately $15.5 million. The net proceeds from these transactions were used to reduce indebtedness under each of the CMM and Legacy CMLP Credit Facilities.
	On September 13, 2013, Inergy Midstream sold 11,000,000 common units at a price of $21.69 per unit providing net proceeds of approximately $238.4 million. On October 7, 2013 the underwriters exercised their option to purchase 773,191 additional common units. The net proceeds were used to repay borrowings under the NRGM Credit Facility.
	Conversion of Limited Partner Units
	On April 1, 2013, Legacy CMLP's outstanding Class C units converted to common units on a one-for-one basis. Prior to the conversion, Legacy CMLP had the option to pay distributions to our Class C unitholders with cash or by issuing additional Paid-in-Kind Class C units, based upon the volume weighted-average price of Legacy CMLP's common units for the 10 trading days immediately preceding the date the distribution was declared. The unitholders of the converted units received a quarterly cash distribution for the period ended March 31, 2013 although the Class C units were not converted until April 1, 2013.
	In January 2013, Legacy CMLP issued 6,190,469 Class D units, representing limited partner interests, to Crestwood Holdings in connection with its acquisition of Crestwood Holdings' 65% interest in CMM. The Class D units are similar in certain respects to Legacy CMLP's common units and Class C units, except that Legacy CMLP has the option to pay distributions to its Class D unitholders with cash or by issuing additional Paid-in-Kind Class D units based on the volume weighted-average price of Legacy CMLP's common units for the 10 trading days immediately preceding the date the distribution is declared. Legacy CMLP issued 151,238 and 141,422 additional Class D units in lieu of paying cash quarterly distributions on the Class D units attributable to the quarters ended March 31, 2013 and June 30, 2013, respectively. In March 2014, Legacy CMLP's outstanding Class D units will convert to common units.
	Quarterly Distributions of Available Cash
	Legacy CMLP paid cash distributions to its common unitholders of $27.4 million and $75.8 million during the three and nine months ended September 30, 2013, and $20.6 million and $56.7 million during the three and nine months ended September 30, 2012. Inergy Midstream paid cash distributions to its common unitholders of $34.2 million during the three months ended September 30, 2013. The Company paid cash distributions to its common unitholders of $22.3 million during the three months ended September 30, 2013.

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	Purchase Commitments
	The Company periodically enters into agreements with suppliers to purchase fixed quantities of NGLs, distillates and natural gas at fixed prices. At September 30, 2013, the total of these firm purchase commitments was $275.0 million, 97.6% of which will occur over the course of the next twelve months. The Company also enters into non-binding agreements with suppliers to purchase quantities of NGLs, distillates and natural gas at variable prices at future dates at the then prevailing market prices.
	The Company and its consolidated subsidiaries entered into certain purchase commitments in connection with the identified growth projects primarily related to the Watkins Glen NGL development project, the COLT Hub expansion project, and certain upgrades to the US Salt facility. The Watkins Glen NGL development project entails the conversion of certain caverns created by US Salt into 2.1 million barrels of NGL storage.  The COLT Hub expansion project primarily includes an expansion of receiving, storage, and take-away capacity via interconnecting pipelines, storage tanks, and rail facilities. At September 30, 2013, the total of the Company's storage and transportation and NGL and crude services operations' firm purchase commitments was approximately $52.0 million. The gathering and processing segment also has purchase commitments of approximately $43.3 million related to other growth and maintenance contractual purchase obligations, as well as environmental obligations. The majority of the purchases associated with these commitments are expected to occur over the course of the next twelve months.
	Capital Leases
	The Company has auto leases, a compressor, and a treating facility that are accounted for as capital leases. The terms of the agreements vary from 2013 until 2016. The Company's capital lease liabilities were $4.2 million and $7.0 million at September 30, 2013 and December 31, 2012, respectively, and are included in accrued expenses and other liabilities and other long-term liabilities on the consolidated balance sheets.
	Legal Proceedings
	Five putative class action lawsuits challenging the Crestwood Merger have been filed, four in federal court in the United States District Court for the Southern District of Texas: (i) Abraham Knoll v. Robert G. Phillips, et al. (Case No. 4:13-cv-01528); (ii) Greg Podell v. Crestwood Midstream Partners, LP, et al. (Case No. 4:13-cv-01599); (iii) Johnny Cooper v. Crestwood Midstream Partners LP, et al. (Case No. 4:13-cv-01660); and (iv) Steven Elliot LLC v. Robert G. Phillips, et al. (Case No. 4:13-cv-01763), and one in Delaware Chancery Court, Hawley v. Crestwood Midstream Partners LP, et al. (Case No. 8689-VCL).  All of the cases name Legacy Crestwood (since merged into the Company), Crestwood Gas Services GP LLC, Crestwood Holdings LLC, the current and former directors of Crestwood Gas Services GP LLC, the Company, Inergy Midstream, Crestwood Midstream GP LLC (formerly NRGM GP, LLC), and Intrepid Merger Sub, LLC as defendants.  All of the suits are brought by a purported holder of common units of Inergy Midstream, both individually and on behalf of a putative class consisting of holders of common units of Inergy Midstream.  The lawsuits generally allege, among other things, that the directors of Crestwood Gas Services GP LLC breached their fiduciary duties to holders of common units of Inergy Midstream by agreeing to a transaction with inadequate consideration and unfair terms and pursuant to an inadequate process.  The lawsuits further allege that the Company, Inergy Midstream, Crestwood Midstream GP LLC, and Intrepid Merger Sub, LLC aided and abetted the Legacy Crestwood directors in the alleged breach of their fiduciary duties.  The lawsuits seek, in general, (i) injunctive relief enjoining the merger, (ii) in the event the merger is consummated, rescission or an award of rescissory damages, (iii) an award of plaintiffs' costs, including reasonable attorneys' and experts' fees, (iv) the accounting by the defendants to plaintiffs for all damages caused by the defendants, and (v) such further equitable relief as the court deems just and proper.  Certain of the actions also assert claims of inadequate disclosure under Sections 14(a) and 20(a) of the Securities Exchange Act of 1934, and the Elliot case also names Citigroup Global Markets Inc. as an alleged aider and abettor.  The plaintiff in the Hawley action in Delaware filed a motion for expedited proceedings but subsequently withdrew that motion and then filed a stipulation voluntarily dismissing the action without prejudice (which has not yet been approved by the Court).  The plaintiffs in the Knoll, Podell, Cooper, and Elliot actions filed an unopposed motion to consolidate these four cases, which the Court granted and captioned the consolidated matter as In re Crestwood Midstream Partners Unitholder Litigation, Lead Case No. 4:13-cv-01528 (the “Consolidated Action”). The plaintiffs entered into a Memorandum of Understanding (MOU) on September 24, 2013 to settle the Consolidated Action whereby the defendants denied liability. The settlement contemplated by the MOU is subject to a number of conditions, including notice to the class and final court approval following completion of a settlement hearing. The defendants expect the Court to approve the terms of the MOU by the end of the first quarter of 2014. The anticipated settlement of the MOU will not have a material impact to our consolidated financial statements.
	In June 2010, Inergy Midstream and CNYOG entered into a letter of intent with Anadarko Petroleum Corporation (“Anadarko”) which contemplated that, subject to certain conditions, Anadarko may exercise an option to acquire up to a 25% ownership interest in the MARC I pipeline. On September 23, 2011, Anadarko filed a complaint against the Company and CNYOG in the Court of Common Pleas in Lycoming County, Pennsylvania (Cause No. 11-01697) alleging that (i) Anadarko had an option to acquire, and timely exercised its option to acquire, a 25% ownership interest in the MARC I pipeline, (ii) the Company refused to enter into definitive agreements under which Anadarko would acquire a 25% interest in the pipeline and, by doing so, the Company breached the letter of intent, and (iii) by refusing to enter into definitive agreements, the Company breached a duty of good faith and fair dealing in connection with the letter of intent. Based on these allegations, Anadarko seeks various remedies, including specific performance of the letter of intent and monetary damages.
	On September 9, 2013, Inergy Midstream and Anadarko entered into a confidential settlement agreement to resolve any and all claims relating to the litigation. CEQP has reimbursed Inergy Midstream for the amount paid to Anadarko under the settlement agreement pursuant to the omnibus agreement that governs Inergy Midstream's relationship with CEQP.
	The Company is periodically involved in litigation proceedings. If the Company determines that a negative outcome is probable and the amount of loss is reasonably estimable, then it accrues the estimated amount. The results of litigation proceedings cannot be predicted with certainty; however, management believes that the Company does not have material potential liability in connection with these proceedings that would have a significant financial impact on its consolidated financial condition, results of operations or cash flows. However, the Company could incur judgments, enter into settlements or revise its expectations regarding the outcome of certain matters, and such developments could have a material adverse effect on the Company's results of operations or cash flows in the period in which the amounts are paid and/or accrued.
	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, the Company is subject to various laws and regulations. In the opinion of the Company's 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
	The Company's operations are subject to stringent and complex laws and regulations pertaining to health, safety, and the environment. The Company is 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 the Company's 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 September 30, 2013, the Company had accrued approximately $0.3 million for environmental matters, which was based on the Company's undiscounted estimate of amounts it will spend on environmental compliance and remediation. The Company estimates that its potential liability for reasonably possible outcomes related to its environmental exposures could range from $0.3 million to $0.5 million. The Company had approximately $0.2 million accrued for environmental matters at December 31, 2012.
	Self-Insurance
	The Company utilizes 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. The Company's self insurance reserves could be affected if future claim developments differ from the historical trends. The Company believes changes in health care costs, trends in health care claims of its employee base, accident frequency and severity and other factors could materially affect the estimate for these liabilities. The Company continually monitors changes in employee demographics, incident and claim type and evaluates its insurance accruals and adjusts its accruals based on its evaluation of these qualitative data points. The Company is liable for the development of claims for its disposed retail propane operations, provided they were reported prior to August 1, 2012. At September 30, 2013, the Company's self-insurance reserves were $17.0 million. The Company estimates that $12.2 million of this balance will be paid subsequent to September 30, 2014. As such, $12.2 million has been classified in other long-term liabilities on the consolidated balance sheets. There were no self-insurance reserves at December 31, 2012.

Segments

Segments	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
Segments	'
	Segments
	In conjunction with the June 19, 2013 transactions described in Note 1, the Company modified its segments and now its financial statements reflect three operating and reporting segments: (i) gathering and processing operations; (ii) NGL and crude services operations; and (iii) storage and transportation operations. The Company's gathering and processing operations engage in the gathering, processing, treating, compression, transportation and sales of natural gas and the delivery of NGLs. The Company's NGL and crude services operations provide NGLs and crude oil marketing, supply and logistics services to producers, refiners, petrochemical companies, marketers, and others that effectively provide flow assurances to our customers, as well as the production and sale of salt products and NGL storage. The Company's storage and transportation operations provide natural gas storage and transportation services to third parties. The Company's corporate operations include all general and administrative expense that is not allocated to the reportable segments. The Company previously evaluated the performance of its operating segments based on gross profit (which the Company defined as operating revenues less product purchases). As a result of Crestwood Holdings’ acquisition of the owner of the Company's general partner on June 19, 2013 and the integration of the Inergy Midstream and CMLP operations, the Company now assesses the performance of its operating segments based on EBITDA, which represents operating income plus depreciation, amortization and accretion expense. In addition, in the quarter ended September 30, 2013, the Company moved the results of its US Salt facility operations and its Bath NGL storage facility operations to the NGL and crude services segment from the storage and transportation segment.
	The identifiable assets associated with each reporting segment include accounts receivable and inventory. Goodwill, property, plant and equipment and cash expenditures for property, plant and equipment are also presented for each segment. The net asset/liability from price risk management, as reported in the accompanying consolidated balance sheets, is primarily related to the NGL and crude services segment.
	The following table is a reconciliation of net income to EBITDA (in millions):
		Three Months Ended					Nine Months Ended
		September 30,					September 30,
		2013			2012		2013			2012
	Net income (loss)	$	(7.9	)	$	9.1	$	(8.5	)	$	21.9
	Add:
	Interest and debt expense, net	22.8			8.9		46.2			25.4
	Provision for income taxes	0.5			0.3		1.2			0.9
	Depreciation, amortization and accretion	55.4			16.9		105.8			51.9
	EBITDA	$	70.8		$	35.2	$	144.7		$	100.1
	The following table summarizes the reportable segment data for the three and nine months ended September 30, 2013 and 2012 (in millions):
		Three Months Ended September 30, 2013
		Gathering and Processing Operations			NGL and Crude Services Operations		Storage and Transportation Operations			Intersegment			Corporate			Total
										Operations			Operations
	Operating revenues	$	71.1		$	307.3	$	48.8		$	—		$	—		$	427.2
	Cost of product/services sold	12.9			270		7.1			—			—			290
	Operating and administrative expense	14.9			15.5		6.8			—			29.1			66.3
	Goodwill impairment	(4.1		)	—		—			—			—			(4.1		)
	Gain on sale of assets	4.4			—		—			—			—			4.4
	Loss on investment in unconsolidated affiliate	(0.4		)	—		—			—			—			(0.4		)
	EBITDA	$	43.2		$	21.8	$	34.9		$	—		$	(29.1	)	$	70.8
	Identifiable assets	$	51.7		$	267	$	18.7		$	(2.8	)	$	—		$	334.6
	Goodwill	$	356.8		$	1,430.80	$	1,133.60		$	—		$	—		$	2,921.20
	Property, plant and equipment	$	1,440.90		$	693.7	$	1,590.80		$	—		$	2.5		$	3,727.90
	Cash expenditures for property, plant and equipment	$	84.2		$	17.9	$	12.4		$	—		$	—		$	114.5
		Three Months Ended September 30, 2012
		Gathering and Processing Operations			NGL and Crude Services Operations		Storage and Transportation Operations			Intersegment			Corporate			Total
										Operations			Operations
	Operating revenues	$	63		$	—	$	—		$	—		$	—		$	63
	Cost of product/services sold	10.3			—		—			—			—			10.3
	Operating and administrative expense	10.9			—		—			—			6.6			17.5
	EBITDA	$	41.8		$	—	$	—		$	—		$	(6.6	)	$	35.2
	Identifiable assets	$	39.5		$	—	$	—		$	—		$	—		$	39.5
	Goodwill	$	352.2		$	—	$	—		$	—		$	—		$	352.2
	Property, plant and equipment	$	1,129.80		$	—	$	—		$	—		$	—		$	1,129.80
	Cash expenditures for property, plant and equipment	$	11.9		$	—	$	—		$	—		$	—		$	11.9
		Nine Months Ended September 30, 2013
		Gathering and Processing Operations			NGL and Crude Services Operations		Storage and Transportation Operations			Intersegment			Corporate			Total
										Operations			Operations
	Operating revenues	$	214.6		$	348.8	$	55.1		$	—		$	—		$	618.5
	Cost of product/services sold	40.4			307.4		7.7			—			—			355.5
	Operating and administrative expense	40.5			17.3		7.7			—			52.7			118.2
	Goodwill impairment	(4.1		)	—		—			—			—			(4.1		)
	Gain on sale of assets	4.4			—		—			—			—			4.4
	Loss on investment in unconsolidated affiliate	(0.4		)	—		—			—			—			(0.4		)
	EBITDA	$	133.6		$	24.1	$	39.7		$	—		$	(52.7	)	$	144.7
	Identifiable assets	$	51.7		$	267	$	18.7		$	(2.8	)	$	—		$	334.6
	Goodwill	$	356.8		$	1,430.80	$	1,133.60		$	—		$	—		$	2,921.20
	Property, plant and equipment	$	1,440.90		$	693.7	$	1,590.80		$	—		$	2.5		$	3,727.90
	Cash expenditures for property, plant and equipment	$	164.5		$	19.1	$	15		$	—		$	—		$	198.6
		Nine Months Ended September 30, 2012
		Gathering and Processing Operations			NGL and Crude Services Operations		Storage and Transportation Operations			Intersegment			Corporate			Total
										Operations			Operations
	Operating revenues	$	172		$	—	$	—		$	—		$	—		$	172
	Cost of product/services sold	26.7			—		—			—			—			26.7
	Operating and administrative expense	30			—		—			—			22			52
	Gain on contingent consideration	6.8			—		—			—			—			6.8
	EBITDA	$	122.1		$	—	$	—		$	—		$	(22.0	)	$	100.1
	Identifiable assets	$	39.5		$	—	$	—		$	—		$	—		$	39.5
	Goodwill	$	352.2		$	—	$	—		$	—		$	—		$	352.2
Property, plant and equipment	$	1,129.80		$	—	$	—		$	—		$	—		$	1,129.80
Cash expenditures for property, plant and equipment	$	34.3		$	—	$	—		$	—		$	—		$	34.3

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	The Company enters into transactions with its affiliates within the ordinary course of business. For a further discussion of the Company's affiliated transactions, see the Form 8-K as filed with the SEC on August 5, 2013. The following table shows revenues, cost of goods sold, operating and administrative expense and reimbursements from the Company's affiliates for the three-month and nine-month periods ended September 30, 2013 and 2012, respectively (in millions):
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2013		2012		2013		2012
	Gathering and processing revenues	$	24.1	$	27.9	$	74.3	$	86.7
	Gathering and processing cost of goods sold	$	7.6	$	—	$	22.2	$	—
	Operating and administrative expense	$	6.1	$	5.1	$	17.2	$	14.6
	Reimbursements	$	0.2	$	0.2	$	0.7	$	0.7
	The following table shows accounts receivable and accounts payable from the Company's affiliates as of September 30, 2013 and December 31, 2012, respectively (in millions):
		September 30, 2013		December 31, 2012
	Accounts receivable	$	22.1	$	23.8
	Accounts payable	$	6.2	$	3.1

Condensed_Consolidating_Financ

Condensed Consolidating Financial Information	9 Months Ended
	Sep. 30, 2013
Text Block [Abstract]	'
Condensed Consolidating Financial Information	'
	Condensed Consolidating Financial Information
	The Company is a holding company and owns no operating assets and has no significant operations independent of its subsidiaries. Obligations under CEQP's outstanding senior notes and credit agreement listed are jointly and severally guaranteed by the Company's wholly owned domestic subsidiaries. Crestwood Midstream and its wholly owned subsidiaries do not guarantee the Company's senior notes or credit facility.
	As discussed in Note 1, the accounting for the Company's acquisition of Legacy CMLP GP results in the historical CEQP operations being acquired on June 19, 2013. The Company's senior notes are thus not included in the financial statements prior to June 19, 2013. Legacy CMLP GP (the accounting predecessor) does not guarantee any debt. Therefore, the condensed consolidated financial statements do not include 2012 financial information.
	The tables below present condensed consolidated financial statements for the Company (parent) on a stand-alone, unconsolidated basis, and its combined guarantor and combined non-guarantor subsidiaries as of September 30, 2013 and for the three-month and nine-month periods ended September 30, 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.
	Condensed Consolidating Balance Sheet
	30-Sep-13
	(in millions)
		Parent			Guarantor			Non-			Eliminations			Consolidated
					Subsidiaries			Guarantor
								Subsidiaries
	Assets
	Current assets:
	Cash and cash equivalents	$	0.1		$	1.8		$	6.9		$	—		$	8.8
	Accounts receivable	—			163.7			78			(2.8		)	238.9
	Inventories	—			89.8			5.9			—			95.7
	Other current assets	—			27.6			17.2			(1.0		)	43.8
	Total current assets	0.1			282.9			108			(3.8		)	387.2
	Property, plant and equipment, net	—			572.9			2,987.20			—			3,560.10
	Goodwill and intangible assets, net	—			1,346.80			2,588.50			—			3,935.30
	Investment in subsidiary	1,784.20			—			—			(1,784.2		)	—
	Other assets	—			10.3			157.5			—			167.8
	Total assets	$	1,784.30		$	2,212.90		$	5,841.20		$	(1,788.0	)	$	8,050.40
	Liabilities and partners' capital
	Current liabilities:
	Accounts payable	$	—		$	192.4		$	20.5		$	(0.8	)	$	212.1
	Other current liabilities	8.1			74.3			105.4			(3.0		)	184.8
	Total current liabilities	8.1			266.7			125.9			(3.8		)	396.9
	Long-term liabilities:
	Long-term debt, less current portion	386.1			—			1,441.30			—			1,827.40
	Other long-term liabilities	22.3			178.7			21.2			—			222.2
	Total long-term liabilities	408.4			178.7			1,462.50			—			2,049.60
	Partners' capital	1,367.80			1,767.50			16.7			(1,784.2		)	1,367.80
	Interest of non-controlling partners in subsidiaries	—			—			4,236.10			—			4,236.10
	Total partners' capital	1,367.80			1,767.50			4,252.80			(1,784.2		)	5,603.90
	Total liabilities and partners' capital	$	1,784.30		$	2,212.90		$	5,841.20		$	(1,788.0	)	$	8,050.40
	Condensed Consolidating Statements of Operations
	Three Months Ended September 30, 2013
	(in millions)
		Parent			Guarantor			Non-			Eliminations			Consolidated
					Subsidiaries			Guarantor
								Subsidiaries
	Revenues:
	Gathering and processing	$	—		$	—		$	71.1		$	—		$	71.1
	NGL and crude services	—			284.1			26.6			(3.4		)	307.3
	Storage and transportation	—			4.6			44.2			—			48.8
		—			288.7			141.9			(3.4		)	427.2
	Cost of product/services sold (excluding depreciation, amortization and accretion as shown below):
	Gathering and processing	—			—			12.9			—			12.9
	NGL and crude services	—			263.1			10.3			(3.4		)	270
	Storage and transportation	—			3.7			3.4			—			7.1
		—			266.8			26.6			(3.4		)	290
	Expenses:
	Operating and administrative	—			17.2			49.1			—			66.3
	Depreciation, amortization and accretion	—			21.4			34			—			55.4
	Other	—			—			(0.3		)	—			(0.3		)
	Operating income (loss)	—			(16.7		)	32.5			—			15.8
	Other income (expense):
	Interest and debt expense, net	(2.7		)	—			(20.1		)	—			(22.8		)
	Other	—			—			(0.4		)	—			(0.4		)
	Equity in net income of subsidiary	(5.1		)	—			—			5.1			—
	Income (loss) before income taxes	(7.8		)	(16.7		)	12			5.1			(7.4		)
	Provision for income taxes	0.1			0.1			0.3			—			0.5
	Net income (loss)	(7.9		)	(16.8		)	11.7			5.1			(7.9		)
Net income attributable to non-controlling partners in subsidiaries	—			—			(0.4		)	—			(0.4		)
Net income (loss) attributable to partners	$	(7.9	)	$	(16.8	)	$	11.3		$	5.1		$	(8.3	)
Condensed Consolidating Statements of Operations
Nine Months Ended September 30, 2013
(in millions)
	Parent			Guarantor			Non-			Eliminations			Consolidated
				Subsidiaries			Guarantor
							Subsidiaries
Revenues:
Gathering and processing	$	—		$	—		$	214.6		$	—		$	214.6
NGL and crude services	—			326			26.6			(3.8		)	348.8
Storage and transportation	—			1.9			53.2						55.1
	—			327.9			294.4			(3.8		)	618.5
Cost of product/services sold (excluding depreciation, amortization and accretion as shown below):
Gathering and processing	—			—			40.4			—			40.4
NGL and crude services	—			300.7			10.5			(3.8		)	307.4
Storage and transportation	—			3.2			4.5						7.7
	—			303.9			55.4			(3.8		)	355.5
Expenses:
Operating and administrative	—			19.7			98.5			—			118.2
Depreciation, amortization and accretion	—			23.5			82.3			—			105.8
Other	—			—			(0.3		)	—			(0.3		)
Operating income (loss)	—			(19.2		)	58.5			—			39.3
Other income (expense):
Interest and debt expense, net	(2.2		)	—			(44.0		)	—			(46.2		)
Other	—			—			(0.4		)	—			(0.4		)
Equity in net income of subsidiary	(6.2		)	—			—			6.2			—
Income (loss) before income taxes	(8.4		)	(19.2		)	14.1			6.2			(7.3		)
Provision for income taxes	0.1			0.1			1			—			1.2
Net income (loss)	(8.5		)	(19.3		)	13.1			6.2			(8.5		)
Net loss attributable to non-controlling partners in subsidiaries	—			—			6.9			—			6.9
Net income (loss) attributable to partners	$	(8.5	)	$	(19.3	)	$	20		$	6.2		$	(1.6	)
Condensed Consolidating Statements of Comprehensive Income
Three Months Ended September 30, 2013
(in millions)
	Parent			Guarantor			Non-			Eliminations			Consolidated
				Subsidiaries			Guarantor
							Subsidiaries
Net income (loss)	$	(7.9	)	$	(16.8	)	$	11.7		$	5.1		$	(7.9	)
Change in Suburban Propane Partners LP units	0.2			—			—			—			0.2
Comprehensive income (loss)	$	(7.7	)	$	(16.8	)	$	11.7		$	5.1		$	(7.7	)
Condensed Consolidating Statements of Comprehensive Income
Nine Months Ended September 30, 2013
(in millions)
	Parent			Guarantor			Non-			Eliminations			Consolidated
				Subsidiaries			Guarantor
							Subsidiaries
Net income (loss)	$	(8.5	)	$	(19.3	)	$	13.1		$	6.2		$	(8.5	)
Change in Suburban Propane Partners LP units	—			—			—			—			—
Comprehensive income (loss)	$	(8.5	)	$	(19.3	)	$	13.1		$	6.2		$	(8.5	)
Condensed Consolidating Statements of Cash Flows
Nine Months Ended September 30, 2013
(in millions)
	Parent			Guarantor			Non-			Eliminations			Consolidated
				Subsidiaries			Guarantor
							Subsidiaries
Cash flows from operating activities	$	—		$	(14.0	)	$	128.1		$	—		$	114.1
Cash flows from investing activities
Acquisitions, net of cash acquired	0.1			5.1			0.9			—			6.1
Purchases of property, plant and equipment	—			(9.7		)	(188.9		)	—			(198.6		)
Investment in unconsolidated affiliate	—			—			(152.5		)	—			(152.5		)
Other	—			0.1			11			—			11.1
Net cash provided by (used in) investing activities	0.1			(4.5		)	(329.5		)	—			(333.9		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	—			216.3			577.2			—			793.5
Principal payments on long-term debt	—			(160.2		)	(568.5		)	—			(728.7		)
Distributions paid	—			(28.9		)	(143.5		)	—			(172.4		)
Distributions paid to non-controlling partners	—			—			(110.0		)	—			(110.0		)
Net proceeds from the issuance of common units	—			—			356.7			—			356.7
Proceeds from issuance of preferred equity	—			—			96.1			—			96.1
Other	—			(6.9		)	0.2			—			(6.7		)
Net cash provided by financing activities	—			20.3			208.2			—			228.5
Net increase in cash	0.1			1.8			6.8			—			8.7
Cash at beginning of period	—			—			0.1			—			0.1
Cash at end of period	$	0.1		$	1.8		$	6.9		$	—		$	8.8

Subsequent_Events

Subsequent Events	9 Months Ended
	Sep. 30, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	Subsequent Events
	On October 24, 2013, the Company declared a distribution of $0.135 per limited partner unit to be paid on November 14, 2013, to unitholders of record on November 7, 2013. On October 24, 2013, Crestwood Midstream also declared a $0.405 per common unit cash distribution payable on November 14, 2013.
	Crestwood Merger
	On October 7, 2013, the Company completed the Crestwood Merger and immediately thereafter merged Legacy CMLP with and into Inergy Midstream, with Inergy Midstream continuing as the surviving entity. In connection with these mergers, Inergy Midstream changed its name to “Crestwood Midstream Partners LP” and changed its NYSE listing symbol to “CMLP,” and the Company changed its name to “Crestwood Equity Partners LP” and changed its NYSE listing symbol to “CEQP.”
	In addition, following the closing of the Crestwood Merger on October 7, 2013, (i) Crestwood Midstream and Finance Corp. assumed the obligations of Legacy CMLP and Crestwood Midstream Finance Corporation under their $350 million in aggregate principal amount of 7.75% senior unsecured notes due April 2019; (ii) certain Legacy CMLP subsidiary guarantors of the 7.75% senior notes due April 2019 guaranteed the obligations of Crestwood Midstream and Finance Corp. under the NRGM Notes; (iii) Crestwood Midstream’s subsidiary guarantors of the NRGM Notes guaranteed obligations of Legacy CMLP and Crestwood Midstream Finance Corporation under the 7.75% senior notes due April 2019; and (iv) Crestwood Midstream Finance Corporation merged with and into NRGM Finance Corp., with NRGM Finance Corp. continuing as the surviving entity, and NRGM Finance Corp. immediately thereafter changed its name to “Crestwood Midstream Finance Corp.”
	Following the closing of the Crestwood Merger, Crestwood Holdings exchanged 7.1 million common units of CMLP for 14.3 million common units of CEQP pursuant to an option obtained on June 19, 2013 when it acquired the general partner of the Company.
	More detailed descriptions of these events are contained in the Forms 8-K filed by Crestwood Midstream with the SEC on October 10, 2013 (the “Merger Form 8-K”).
	New Secured Revolving Credit Facility
	Immediately following the Crestwood Merger, on October 7, 2013, Crestwood Midstream entered into a new five-year senior secured credit facility under which at least $1 billion of cash borrowing capacity will be made available to Crestwood Midstream and its subsidiaries by a syndicate of financial institutions. Crestwood Midstream borrowed $623.6 million of funds under the Crestwood Midstream Revolver to repay in full and retire the NRGM Credit Facility, the Legacy CMLP Credit Facility, and the CMM Credit Facility. Subject to limited exception, the new credit facility is secured by substantially all of the equity interests and assets of Crestwood Midstream’s restricted domestic subsidiaries, and is joint and severally guaranteed by substantially all of its restricted domestic subsidiaries. A more detailed description of the Crestwood Midstream Revolver is contained in the Merger Form 8-K.
	Arrow Midstream Holdings, LLC Acquisition
	On October 8, 2013, Crestwood Midstream and its wholly-owned subsidiary, Crestwood Arrow Acquisition LLC ("Crestwood Arrow"), entered into an agreement to acquire Arrow Midstream Holdings, LLC ("Arrow"), a privately-held midstream company, for approximately $750 million, subject to customary capital expenditure and working capital adjustments.  Under the merger agreement, Crestwood Arrow will merge with and into Arrow (the “Arrow Acquisition”), with Arrow continuing as the surviving entity and a wholly-owned subsidiary of Crestwood Midstream. The base merger consideration consists of $550 million in cash and 8,826,125 common units of Crestwood Midstream to be issued to the sellers, subject to adjustment. The transaction is expected to close on November 8, 2013.
	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. The system today consists of over 460 miles of gathering pipeline including 150 miles of crude oil gathering pipeline, 160 miles of natural gas gathering pipeline, and 150 miles of water gathering lines. Current volumes on the system are approximately 50,000 barrels per day ("Bbls/d") of crude oil, 15 million cubic feet per day of rich natural gas and 8,500 Bbls/d of water. Additionally, the acquired assets include salt water disposal wells and a 23-acre central delivery point with multiple pipeline take-away outlets and a fully-automated truck loading facility. The Arrow systems are currently being expanded to increase gathering capacities to 125,000 Bbls/d of crude oil, 100 MMcf/d of natural gas, and 40,000 Bbls/d of produced water.
	Crestwood Midstream Equity Offerings
	On October 7, 2013, Crestwood Midstream sold 773,191 common units at $21.69 per unit pursuant to an underwriters’ option to purchase additional common units, as such option was granted to the underwriters by Crestwood Midstream in its September 2013 equity offering. The sale generated approximately $16.8 million of net proceeds after deducting underwriters’ discounts, commission and other offering expenses. Proceeds were used to repay borrowings under the Crestwood Midstream Revolver.
	On October 23, 2013, Crestwood Midstream sold 14,000,000 common units to underwriters at $21.19 per unit in a registered public offering generating net proceeds of approximately $296.4 million after deducting underwriters’ discounts, commission and other offering expenses. Proceeds will be used to pay a portion of the base merger consideration to the sellers in the Arrow Acquisition and to pay related fees and expenses. On October 30, 2013, Crestwood Midstream sold 2,100,000 common units at $21.19 per unit pursuant to an underwriters' option to purchase additional common units, as such option was granted to the underwriters by Crestwood Midstream in its October 23, 2013 equity offering.
	Crestwood Midstream Senior Notes Offering
	On October 22, 2013, Crestwood Midstream and Finance Corp. announced an offering of $600 million in aggregate principal amount of 6.125% senior notes due 2022 in a private offering exempt from the registration requirements of the Securities Act of 1933.  The notes will be guaranteed on a senior unsecured basis by substantially all of Crestwood Midstream’s existing and future domestic restricted subsidiaries (other than Finance Corp.), subject to certain exceptions.  Crestwood Midstream expects to close the private placement on November 8, 2013.  Crestwood Midstream anticipates using the net offering proceeds to fund a portion of the consideration payable in the Arrow Acquisition and pay related fees and expenses, and to repay borrowings under the Crestwood Midstream Revolver.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2013
Text Block [Abstract]	'
Financial Instruments and Price Risk Management	'
	Financial Instruments and Price Risk Management
	The Company utilizes certain derivative financial instruments to (i) manage its 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 adequate physical supply of commodity will be available; and (iii) manage its exposure to the interest rate risk associated with fixed and variable rate borrowings. The Company records all derivative instruments on the balance sheet as either assets or liabilities measured at fair value. Changes in the fair value of these derivative financial instruments are recorded either through current earnings or as other comprehensive income, depending on the type of transaction.
	The Company is periodically party to certain commodity derivative financial instruments that are designated as hedges of selected inventory positions. Certain of these instruments may be designated as fair value hedges for accounting purposes. The Company is also periodically party to certain interest rate swap agreements designed to manage interest rate risk exposure. The Company’s overall objective for entering into hedges is to manage its exposure to fluctuations in commodity prices and changes in the fair market value of its inventories and fixed and variable rate borrowings. The commodity derivatives are recorded at fair value on the balance sheets as price risk management assets or liabilities and the related change in fair value is recorded to earnings in the current period as cost of product/services sold.
	The Company had no derivatives identified as fair value hedges for accounting purposes in the three-month and nine-month periods ended September 30, 2013 and 2012.
	The Company also enters into derivative financial instruments that may qualify as cash flow hedges, which hedge the exposure of variability in expected future cash flows predominantly attributable to variable interest payments. These derivatives are recorded on the balance sheet at fair value as other assets or other long-term liabilities. The effective portion of the gain or loss on these cash flow hedges is recorded in other comprehensive income in partner's capital and reclassified into earnings in the same period in which the hedge transaction affects earnings. In certain situations under the rules, the ineffective portion of the gain or loss is recognized as cost of product sold/services sold or interest expense in the current period. The Company did not have any derivatives designated as cash flow hedges in the three-month and nine-month periods ended September 30, 2013 and 2012.
	The Company’s policy is to offset fair value amounts of derivative instruments and cash collateral paid or received with the same counterparty under a master netting arrangement.
	The cash flow impact of derivative financial instruments is reflected as cash flows from operating activities in the consolidated statements of cash flows.
Revenue Recognition	'
	Revenue Recognition
	The Company's gathering and processing operations gather, process, treat, compress, transport and sell natural gas pursuant to fixed-fee and percent-of-proceeds contracts. For fixed-fee contracts, the Company recognizes revenues based on the volume of natural gas gathered, processed and treated or compressed. For percent-of-proceeds contracts, the Company recognizes revenues based on the value of products sold to third parties. The Company recognizes revenues for these services and products when all of the following criteria are met:
	• services have been rendered or products delivered;
	• persuasive evidence of an exchange arrangement exists;
	• the price for services is fixed or determinable; and
	• collectability is reasonably assured.
	Sales of NGLs and salt are recognized at the time product is shipped or delivered to the customer depending on the sales terms. NGL processing and fractionation fees are recognized upon delivery of the product. Revenues from the COLT Hub are recognized when the contractual services are provided, such as loading of customer rail cars. Revenues from storage and transportation contracts are recognized during the period in which the storage and transportation services are provided, such as providing storage and transportation services during the period a firm service contract is in place.
Credit Risk and Concentrations	'
	Credit Risk and Concentrations
	Inherent in the Company's contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. The Company takes an active role in managing credit risk and has established control procedures, which are reviewed on an ongoing basis. The Company attempts 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.
	Two customers, Quicksilver Resources Inc. (“Quicksilver”) and Antero Resources Appalachian Corporation (“Antero”), accounted for approximately 44% and 13% of the Company's total revenue for the three months ended September 30, 2012, respectively. No customers accounted for 10% or more of the Company's total revenue in the three months ended September 30, 2013. Quicksilver accounted for approximately 12% and 50% of the Company's total revenue for the nine months ended September 30, 2013 and 2012, respectively.  No other customer accounted for 10% or more of the Company's total revenue in those periods. All Quicksilver and Antero revenues are captured in the gathering and processing segment.
	At December 31, 2012, Quicksilver and Antero accounted for approximately 48% and 14% of the Company's consolidated accounts receivable, respectively. No customer accounted for 10% or more of the Company's consolidated accounts receivable at September 30, 2013.
Use of Estimates	'
	Use of Estimates
	The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the periods presented. Actual results could differ from those estimates.
Inventories	'
	Inventory
	Inventory for NGL and crude services operations, which mainly consist of NGLs, are stated at the lower of cost or market and are computed using the average cost method. Inventory for storage and transportation operations are stated at the lower of cost or market and are computed predominantly using the average cost method. Legacy CMLP GP had no inventory at December 31, 2012.
Shipping and Handling Costs	'
	Shipping and Handling Costs
	Shipping and handling costs are recorded as part of cost of product/services sold at the time product is shipped or delivered to the customer.
Property, Plant and Equipment	'
	Property, Plant and Equipment
	Property, plant and equipment is recorded at its original cost of construction or, upon acquisition, at fair value of the assets acquired. For assets the Company constructs, it capitalizes direct costs, such as labor and materials, and indirect costs, such as overhead and interest. The Company capitalizes major units of property replacements or improvements and expenses minor items. Depreciation is computed by the straight-line method over the estimated useful lives of the assets, as follows:
		Years
	Gathering systems	20
	Processing plants and compression facilities	20 – 25
	Buildings, rights-of-way, easements and storage rights	20 – 70
	Office furniture and equipment	5 – 10
	Vehicles	5
	Pipelines	20
	Base gas	10
	Salt deposits are depleted utilizing the unit of production method.
	Accrued Additions to Property, Plant and Equipment
	The Company has accrued for property, plant and equipment, including certain construction work in process relating to construction efforts on various growth projects. At September 30, 2013 and December 31, 2012, the Company had accrued $47.4 million and $9.2 million relating to property, plant and equipment classified as accrued expenses on the consolidated balance sheets.
Identifiable Intangible Assets	'
	Identifiable Intangible Assets
	The Company has recorded certain identifiable intangible assets, including customer accounts, covenants not to compete, trademarks, deferred financing costs and gas gathering, compression and processing contracts. Customer accounts, covenants not compete and trademarks have arisen from acquisitions. Deferred financing costs represent financing costs incurred in obtaining financing and are being amortized over the term of the related debt using the effective interest method. The Company recognizes acquired intangible asset 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.
	Customer accounts, covenants not to compete and trademarks are generally amortized on a straight-line basis over their estimated economic lives, typically 10 years, 2 - 9 years and 5 - 10 years, respectively. The customer accounts associated with the NGL and crude services segment and the gas gathering, compression and processing contracts are generally amortized based on the projected cash flows associated with the contracts, typically 5 - 20 years.
Goodwill	'
	Goodwill
	Goodwill is recognized for various acquisitions as the excess of the cost of the acquisitions over the fair value of the related net assets at the date of acquisition. Goodwill is subject to at least an annual assessment for impairment by applying a fair-value-based test.
	The Company completed its annual impairment test for each of its reporting units and determined that no impairment existed as of December 31, 2012. During the three months ended September 30, 2013, the Company recorded an impairment of goodwill of approximately $4.1 million on its Haynesville/Bossier Shale system as a result of a decrease in anticipated revenues to be generated from those operations due primarily to the Company's inability to renew and extend a significant revenue contract that expired in mid-2013.
Investment in Unconsolidated Affiliate	'
	Investment in Unconsolidated Affiliate
	The Company applies the equity method of accounting where it can exert significant influence over, but does not control or direct, the policies, decisions or activities of the entity. The Company uses the cost method of accounting where it is unable to exert significant influence over the entity. The FASB's accounting standards related to equity method investments and joint ventures requires entities to periodically review their equity method investments to determine whether current events or circumstances indicate that the carrying value of the equity method investment may be impaired. The Company evaluates its equity method investment for impairment when there are indicators of impairment. If indicators suggest impairment, the Company will perform an impairment test to assess whether an adjustment is necessary. The impairment test considers whether the fair value of the Company's equity method investment declined and if any such decline is other than temporary. If a decline in fair value is determined to be other than temporary, the investment's carrying value is written down to fair value.
Income Taxes	'
	Income Taxes
	The Company is a publicly-traded master limited partnership. Partnerships are generally not subject to federal income tax, although publicly-traded partnerships are treated as corporations for federal income tax purposes and therefore are subject to federal income tax, unless the partnership generates at least 90% of its gross income from qualifying sources. If the qualifying income requirement is satisfied, the publicly-traded partnership will be treated as a partnership for federal income tax purposes. The earnings of the Company and its limited liability subsidiaries are included in the federal and state income tax returns of the individual members or partners. However, legislation in certain states allows for taxation of partnerships, and as such, certain state taxes for the Company have been included in the 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. The Company is 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 differences are expected to reverse.
	The Company is responsible for its portion of the Texas Margin tax that is included in Crestwood Holdings' consolidated Texas franchise tax return. The Company's current tax liability will be assessed based on 0.7% of the gross revenue apportioned to Texas. The margin tax qualifies as an income tax under GAAP, which requires the Company 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.
Sales Tax	'
	Sales Tax
	The Company accounts for the collection and remittance of sales tax on a net tax basis. As a result, these amounts are not reflected in the consolidated statements of operations.
Income Per Unit	'
	Income Per Unit
	The Company calculates basic net income per limited partner unit by utilizing the two class method. Diluted net income per limited partner unit is computed by dividing net income attributable to the limited partners by the weighted-average number of units outstanding and the effect of dilutive units granted in the Company's acquisition of Legacy CMLP GP. Net income attributable to the limited partners is determined by first allocating to the Company the earnings from the IDR interests from Crestwood Midstream (or, prior to the Crestwood Merger, the general partner and IDR interests of Inergy Midstream and Legacy CMLP) with the remaining earnings allocated according to the capital accounts. The weighted average number of units outstanding is calculated based on the presumption that the common and subordinated units issued to acquire Legacy CMLP GP (the accounting predecessor) were outstanding for the entire period prior to the June 19, 2013 acquisition. On the date of the acquisition, all of the Company's limited partner units are considered outstanding.
Asset Retirement Obligations	'
	Asset Retirement Obligations
	An asset retirement obligation ("ARO") is an estimated liability for the cost to retire a tangible asset. The Company records a liability for legal or contractual obligations to retire its long-lived assets associated with right-of-way contracts it holds and its facilities whether owned or leased. The Company records 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 value of the liability as a result of the passage of time, which the Company records as depreciation, amortization and accretion expense on its consolidated statements of operations. The fair value of certain AROs could not be determined as settlement dates (or range of dates) associated with these assets were not estimable. The net AROs were $14.6 million and $14.0 million at September 30, 2013 and December 31, 2012, respectively, and are included in other long-term liabilities on the consolidated balance sheets.
Accounting For Unit-Based Compensation	'
	Accounting for Unit-Based Compensation
	Unit-based compensation awards are valued at the closing market price of our 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. The Company generally recognizes the expense associated with the award over the vesting period. At the time of issuance of phantom units, management of the General Partner determines whether they will be settled in cash or settled in common units. Unit-based compensation awards at Inergy Midstream and Legacy Crestwood are fully reflected in these financial statements and are accounted for in the manner described above.
	The amount of compensation expense recorded by the Company was $5.6 million and $0.5 million during the three months ended September 30, 2013 and 2012, respectively, and $7.6 million and $1.5 million during the nine months ended September 30, 2013 and 2012, respectively.
Segment Information	'
	Segment Information
	There are certain accounting requirements that establish standards for reporting information about operating segments, as well as related disclosures about products and services, geographic areas and major customers. Further, they define operating segments as components of an enterprise for which separate financial information is available that is evaluated regularly by the chief operating decision maker in deciding how to allocate resources and assess performance. In determining its operating segments, the Company examined the way it organizes its business internally for making operating decisions and assessing business performance. See Note 10 for disclosures related to the Company’s three operating and reporting segments.
Fair Value	'
	Fair Value
	Cash and Cash Equivalents, Accounts Receivable and Accounts Payable
	As of September 30, 2013 and December 31, 2012, the carrying amounts of cash and cash equivalents, accounts receivable (net of allowance for doubtful accounts) and accounts payable represent fair value due to their liquid and short-term nature.
	Credit Facilities
	The fair value of the Company's credit agreement and all of its credit facilities approximates their carrying amounts as of September 30, 2013 and December 31, 2012 due primarily to the variable nature of the interest rates of the instruments.
	Senior Notes
	The Company estimates the fair value of its senior notes primarily based on quoted market prices for the same or similar issuances. This valuation methodology is considered level 2 in the fair value hierarchy. The following table reflects the carrying value and fair value of the senior notes (in millions):
		September 30, 2013				December 31, 2012
		Carrying Amount		Fair		Carrying Amount		Fair
				Value				Value
	CEQP senior unsecured notes	$	11.5	$	11.5	$	—	$	—
	Legacy CMLP senior unsecured notes	$	351.3	$	369.3	$	351.5	$	365.9
	NRGM senior unsecured notes	$	500	$	497.8	$	—	$	—
	See Note 6 for a discussion of the Company's assets and liabilities recorded at fair value on the balance sheet.
Recently Issued Accounting Pronouncements	'
	Recently Issued Accounting Pronouncements
	On December 16, 2011, the FASB issued ASU No. 2011-11, “Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities.” This ASU requires disclosures to provide information to help reconcile differences in the offsetting requirements under U.S. Generally Accepted Accounting Principles and International Financial Reporting Standards. The disclosure requirements of this ASU mandate that entities disclose both gross and net information about financial instruments and transactions eligible for offset in the statement of financial position as well as instruments and transactions subject to an enforceable master netting arrangement or similar agreement. ASU No. 2011-11 also requires disclosure of collateral received and posted in connection with master netting arrangements or similar arrangements. The scope of this ASU includes derivative contracts, repurchase agreements, and securities borrowing and lending arrangements. Entities are required to apply the amendments of ASU No. 2011-11 for annual reporting periods beginning on or after January 1, 2013, and interim periods within those annual periods. All disclosures provided by those amendments are required to be provided retrospectively for all comparative periods presented. The Company adopted the effects of ASU No. 2011-11 on January 1, 2013.
	On February 5, 2013, the FASB issued ASU No. 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income.” This ASU amends and clarifies the disclosure requirements prescribed in ASU No. 2011-05, “Comprehensive Income (Topic 220): Presentation of Comprehensive Income.” ASU No. 2013-02 requires that entities present information about reclassification adjustments from accumulated other comprehensive income in their annual financial statements in a single note or on the face of the financial statements. Public entities will also have to provide this information in their interim financial statements. Specifically, entities must present, either in a single note or parenthetically on the face of the financial statements, the effect of significant amounts reclassified from each component of accumulated other comprehensive income based on its source and the income statement line items affected by the reclassification. If a component is not required to be reclassified to net income in its entirety, entities would instead cross reference to the related footnote for additional information.  The Company adopted the requirements of ASU No. 2013-02 on January 1, 2013 and presented the required information in a single note.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2013
Text Block [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	20
	Processing plants and compression facilities	20 – 25
	Buildings, rights-of-way, easements and storage rights	20 – 70
	Office furniture and equipment	5 – 10
	Vehicles	5
	Pipelines	20
	Base gas	10
Schedule of Carrying and Fair Values of Senior Notes [Table Text Block]	'
	The following table reflects the carrying value and fair value of the senior notes (in millions):
		September 30, 2013				December 31, 2012
		Carrying Amount		Fair		Carrying Amount		Fair
				Value				Value
	CEQP senior unsecured notes	$	11.5	$	11.5	$	—	$	—
	Legacy CMLP senior unsecured notes	$	351.3	$	369.3	$	351.5	$	365.9
	NRGM senior unsecured notes	$	500	$	497.8	$	—	$	—

Certain_Balance_Sheet_Informat1

Certain Balance Sheet Information (Tables)	9 Months Ended
	Sep. 30, 2013
Balance Sheet Related Disclosures [Abstract]	'
Inventories	'
	Inventory consisted of the following at September 30, 2013 and December 31, 2012, respectively (in millions):
		September 30,		December 31,
		2013		2012
	NGLs	$	88.8	$	—
	Parts, supplies and other	6.9		—
	Total inventory	$	95.7	$	—
Property, Plant And Equipment	'
	Property, plant and equipment consisted of the following at September 30, 2013 and December 31, 2012, respectively (in millions):
		September 30,		December 31,
		2013		2012
	Gathering systems	$	662.5	$	582.3
	Processing plants and compression facilities	544.5		485.4
	Plant equipment	522.3		—
	Buildings, rights-of-way and easements	75.2		66.4
	Land and storage rights	755.7		4.1
	Pipelines	661		—
	Vehicles	32.9		0.3
	Construction in process	246.6		56
	Base gas	97.9		—
	Salt deposits	120.5		—
	Office furniture and equipment	8.8		2.9
		3,727.90		1,197.40
	Less: accumulated depreciation	167.8		95
	Total property, plant and equipment, net	$	3,560.10	$	1,102.40
Intangible Assets	'
	Intangible assets consisted of the following at September 30, 2013 and December 31, 2012, respectively (in millions):
		September 30,		December 31,
		2013		2012
	Customer accounts	$	231	$	—
	Covenants not to compete	7		—
	Gas gathering, compression and processing contracts	750.1		813
	Acquired storage contracts	43.5		—
	Trademarks	33.5		—
	Deferred financing and other costs	33.8		32.2
		1,098.90		845.2
	Less: accumulated amortization	84.8		49.9
	Total intangible assets, net	$	1,014.10	$	795.3

Business_Acquisitions_Tables

Business Acquisitions (Tables)	9 Months Ended
	Sep. 30, 2013
Business Combinations [Abstract]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	'
	The following table summarizes the estimated fair values of the assets acquired and liabilities assumed at the merger date (in millions):
		June 19,		Preliminary Estimate (a)			Adjustment Based on Revised Valuation Report
		2013
	Current assets	$	222.7	$	222.7		$	—
	Property, plant and equipment	2,259.70		2,554.90			(295.2		)
	Intangible assets	315		273			42
	Other assets	12.7		51.2			(38.5		)
	Total identifiable assets acquired	2,810.10		3,101.80			(291.7		)
	Current liabilities	208.9		205.5			3.4
	Long-term debt	1,079.30		1,079.30			—
	Other long-term liabilities	213.1		43.9			169.2
	Total liabilities assumed	1,501.30		1,328.70			172.6
	Net identifiable assets acquired	1,308.80		1,773.10			(464.3		)
	Goodwill	2,564.40		2,100.10			464.3
	Net assets acquired	$	3,873.20	$	3,873.20		$	—
	(a)    Provisional amount recorded as of June 30, 2013.
Business Acquisition, Pro Forma Information	'
	The following table represents the pro forma consolidated statements of operations as if the reverse acquisition had been included in the consolidated results of the Company for the three-month period ended September 30, 2012 and for the full nine-month periods ended September 30, 2013 and 2012 (in millions, except per unit information):
		Pro Forma Consolidated
		Statement of Operations
		(Unaudited)
		Three Months Ended		Nine Months Ended
		September 30,		September 30,
		2012 (a)		2013			2012 (a)
	Revenues	$	333.7	$	1,339.90		$	1,026.40
	Net income (loss)	$	73.2	$	(34.2	)	$	105.1
	Net income (loss) per limited partner unit:
	Basic	$	1.9	$	(0.33	)	$	2.42
	Diluted	$	1.69	$	(0.33	)	$	2.15
	(a)	The three-month and nine-month periods ended September 30, 2012 have also been adjusted to reflect the contribution of the Company's retail operations to Suburban Propane Partners on August 1, 2012 as if that contribution had been removed from the consolidated results of operations at the beginning of each period presented.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2013
Fair Value, Assets and Liabilities Measured on Recurring Basis [Abstract]	'
Assets And Liabilities Measured At Fair Value On Recurring Basis	'
	The following tables set forth by level within the fair value hierarchy the Company's assets and liabilities that were accounted for at fair value on a recurring basis at September 30, 2013 (in millions):
		30-Sep-13
		Fair Value of Derivatives
		Level 1		Level 2		Level 3		Total		Designated		Not		Netting			Total
										as Hedges		Designated		Agreements(a)
												as Hedges
	Assets
	Assets from price risk management	$	0.3	$	35.9	$	—	$	36.2	$	—	$	36.2	$	(12.5	)	$	23.7
	SPH units	6.6		—		—		6.6		—		6.6		—			6.6
	Total assets at fair value	$	6.9	$	35.9	$	—	$	42.8	$	—	$	42.8	$	(12.5	)	$	30.3
	Liabilities
	Liabilities from price risk management	$	0.3	$	29.7	$	—	$	30	$	—	$	30	$	1.9		$	31.9
	Interest rate swaps	—		4.8		—		4.8		—		4.8		—			4.8
	Total liabilities at fair value	$	0.3	$	34.5	$	—	$	34.8	$	—	$	34.8	$	1.9		$	36.7
	(a)	Amounts represent the impact of legally enforceable master netting agreements that allow the Company to settle positive and negative positions as well as cash collateral held or placed with the same counterparties.

Risk_Management_Tables

Risk Management (Tables)	9 Months Ended
	Sep. 30, 2013
Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]	'
Notional Amounts And Terms Of Company's Derivative Financial Instruments	'
	The notional amounts and terms of the Company’s derivative financial instruments include the following at September 30, 2013 and December 31, 2012, respectively (in millions):
		30-Sep-13		31-Dec-12
		Fixed Price	Fixed Price	Fixed Price	Fixed Price
		Payor	Receiver	Payor	Receiver
	Propane, crude and heating oil (barrels)	7.2	8.8	—	—

LongTerm_Debt_Tables

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2013
Text Block [Abstract]	'
Components Of Long-Term Debt	'
	Long-term debt consisted of the following at September 30, 2013 and December 31, 2012, respectively (in millions):
		September 30,		December 31,
		2013		2012
	CEQP credit agreement	$	376.2	$	—
	CEQP senior notes	11.5		—
	CEQP obligations under noncompetition agreements and notes to former owners of businesses acquired	2.9		—
	Legacy CMLP credit facility	356.2		206.7
	Legacy CMLP senior notes	350		350
	Premium on Legacy CMLP senior notes	1.3		1.5
	CMM credit facility	191.9		127
	NRGM credit facility	37		—
	NRGM senior notes	500		—
	Fair value adjustment of NRGM senior notes	4.8		—
	Total debt	1,831.80		685.2
	Less: current portion	4.4		—
	Total long-term debt	$	1,827.40	$	685.2

Segments_Tables

Segments (Tables)	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
Reconciliation of Net Income (Loss) to Earnings Before Interest, Taxes, Depreciation and Amortization [Table Text Block]	'
	The following table is a reconciliation of net income to EBITDA (in millions):
		Three Months Ended					Nine Months Ended
		September 30,					September 30,
		2013			2012		2013			2012
	Net income (loss)	$	(7.9	)	$	9.1	$	(8.5	)	$	21.9
	Add:
	Interest and debt expense, net	22.8			8.9		46.2			25.4
	Provision for income taxes	0.5			0.3		1.2			0.9
	Depreciation, amortization and accretion	55.4			16.9		105.8			51.9
	EBITDA	$	70.8		$	35.2	$	144.7		$	100.1
Summary Of Segment Information	'
	The following table summarizes the reportable segment data for the three and nine months ended September 30, 2013 and 2012 (in millions):
		Three Months Ended September 30, 2013
		Gathering and Processing Operations			NGL and Crude Services Operations		Storage and Transportation Operations			Intersegment			Corporate			Total
										Operations			Operations
	Operating revenues	$	71.1		$	307.3	$	48.8		$	—		$	—		$	427.2
	Cost of product/services sold	12.9			270		7.1			—			—			290
	Operating and administrative expense	14.9			15.5		6.8			—			29.1			66.3
	Goodwill impairment	(4.1		)	—		—			—			—			(4.1		)
	Gain on sale of assets	4.4			—		—			—			—			4.4
	Loss on investment in unconsolidated affiliate	(0.4		)	—		—			—			—			(0.4		)
	EBITDA	$	43.2		$	21.8	$	34.9		$	—		$	(29.1	)	$	70.8
	Identifiable assets	$	51.7		$	267	$	18.7		$	(2.8	)	$	—		$	334.6
	Goodwill	$	356.8		$	1,430.80	$	1,133.60		$	—		$	—		$	2,921.20
	Property, plant and equipment	$	1,440.90		$	693.7	$	1,590.80		$	—		$	2.5		$	3,727.90
	Cash expenditures for property, plant and equipment	$	84.2		$	17.9	$	12.4		$	—		$	—		$	114.5
		Three Months Ended September 30, 2012
		Gathering and Processing Operations			NGL and Crude Services Operations		Storage and Transportation Operations			Intersegment			Corporate			Total
										Operations			Operations
	Operating revenues	$	63		$	—	$	—		$	—		$	—		$	63
	Cost of product/services sold	10.3			—		—			—			—			10.3
	Operating and administrative expense	10.9			—		—			—			6.6			17.5
	EBITDA	$	41.8		$	—	$	—		$	—		$	(6.6	)	$	35.2
	Identifiable assets	$	39.5		$	—	$	—		$	—		$	—		$	39.5
	Goodwill	$	352.2		$	—	$	—		$	—		$	—		$	352.2
	Property, plant and equipment	$	1,129.80		$	—	$	—		$	—		$	—		$	1,129.80
	Cash expenditures for property, plant and equipment	$	11.9		$	—	$	—		$	—		$	—		$	11.9
		Nine Months Ended September 30, 2013
		Gathering and Processing Operations			NGL and Crude Services Operations		Storage and Transportation Operations			Intersegment			Corporate			Total
										Operations			Operations
	Operating revenues	$	214.6		$	348.8	$	55.1		$	—		$	—		$	618.5
	Cost of product/services sold	40.4			307.4		7.7			—			—			355.5
	Operating and administrative expense	40.5			17.3		7.7			—			52.7			118.2
	Goodwill impairment	(4.1		)	—		—			—			—			(4.1		)
	Gain on sale of assets	4.4			—		—			—			—			4.4
	Loss on investment in unconsolidated affiliate	(0.4		)	—		—			—			—			(0.4		)
	EBITDA	$	133.6		$	24.1	$	39.7		$	—		$	(52.7	)	$	144.7
	Identifiable assets	$	51.7		$	267	$	18.7		$	(2.8	)	$	—		$	334.6
	Goodwill	$	356.8		$	1,430.80	$	1,133.60		$	—		$	—		$	2,921.20
	Property, plant and equipment	$	1,440.90		$	693.7	$	1,590.80		$	—		$	2.5		$	3,727.90
	Cash expenditures for property, plant and equipment	$	164.5		$	19.1	$	15		$	—		$	—		$	198.6
		Nine Months Ended September 30, 2012
		Gathering and Processing Operations			NGL and Crude Services Operations		Storage and Transportation Operations			Intersegment			Corporate			Total
										Operations			Operations
	Operating revenues	$	172		$	—	$	—		$	—		$	—		$	172
	Cost of product/services sold	26.7			—		—			—			—			26.7
	Operating and administrative expense	30			—		—			—			22			52
	Gain on contingent consideration	6.8			—		—			—			—			6.8
	EBITDA	$	122.1		$	—	$	—		$	—		$	(22.0	)	$	100.1
	Identifiable assets	$	39.5		$	—	$	—		$	—		$	—		$	39.5
	Goodwill	$	352.2		$	—	$	—		$	—		$	—		$	352.2
	Property, plant and equipment	$	1,129.80		$	—	$	—		$	—		$	—		$	1,129.80
	Cash expenditures for property, plant and equipment	$	34.3		$	—	$	—		$	—		$	—		$	34.3

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Schedule of Related Party Transactions	'
	The following table shows revenues, cost of goods sold, operating and administrative expense and reimbursements from the Company's affiliates for the three-month and nine-month periods ended September 30, 2013 and 2012, respectively (in millions):
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2013		2012		2013		2012
	Gathering and processing revenues	$	24.1	$	27.9	$	74.3	$	86.7
	Gathering and processing cost of goods sold	$	7.6	$	—	$	22.2	$	—
	Operating and administrative expense	$	6.1	$	5.1	$	17.2	$	14.6
	Reimbursements	$	0.2	$	0.2	$	0.7	$	0.7
Schedule of Related Party Receivables and Payables	'
	The following table shows accounts receivable and accounts payable from the Company's affiliates as of September 30, 2013 and December 31, 2012, respectively (in millions):
		September 30, 2013		December 31, 2012
	Accounts receivable	$	22.1	$	23.8
	Accounts payable	$	6.2	$	3.1

Condensed_Consolidating_Financ1

Condensed Consolidating Financial Information (Tables)	9 Months Ended
	Sep. 30, 2013
Text Block [Abstract]	'
Condensed Consolidating Balance Sheet	'
	Condensed Consolidating Balance Sheet
	30-Sep-13
	(in millions)
		Parent			Guarantor			Non-			Eliminations			Consolidated
					Subsidiaries			Guarantor
								Subsidiaries
	Assets
	Current assets:
	Cash and cash equivalents	$	0.1		$	1.8		$	6.9		$	—		$	8.8
	Accounts receivable	—			163.7			78			(2.8		)	238.9
	Inventories	—			89.8			5.9			—			95.7
	Other current assets	—			27.6			17.2			(1.0		)	43.8
	Total current assets	0.1			282.9			108			(3.8		)	387.2
	Property, plant and equipment, net	—			572.9			2,987.20			—			3,560.10
	Goodwill and intangible assets, net	—			1,346.80			2,588.50			—			3,935.30
	Investment in subsidiary	1,784.20			—			—			(1,784.2		)	—
	Other assets	—			10.3			157.5			—			167.8
	Total assets	$	1,784.30		$	2,212.90		$	5,841.20		$	(1,788.0	)	$	8,050.40
	Liabilities and partners' capital
	Current liabilities:
	Accounts payable	$	—		$	192.4		$	20.5		$	(0.8	)	$	212.1
	Other current liabilities	8.1			74.3			105.4			(3.0		)	184.8
	Total current liabilities	8.1			266.7			125.9			(3.8		)	396.9
	Long-term liabilities:
	Long-term debt, less current portion	386.1			—			1,441.30			—			1,827.40
	Other long-term liabilities	22.3			178.7			21.2			—			222.2
	Total long-term liabilities	408.4			178.7			1,462.50			—			2,049.60
	Partners' capital	1,367.80			1,767.50			16.7			(1,784.2		)	1,367.80
	Interest of non-controlling partners in subsidiaries	—			—			4,236.10			—			4,236.10
	Total partners' capital	1,367.80			1,767.50			4,252.80			(1,784.2		)	5,603.90
	Total liabilities and partners' capital	$	1,784.30		$	2,212.90		$	5,841.20		$	(1,788.0	)	$	8,050.40
	Condensed Consolidating Statements of Operations
	Three Months Ended September 30, 2013
	(in millions)
		Parent			Guarantor			Non-			Eliminations			Consolidated
					Subsidiaries			Guarantor
								Subsidiaries
	Revenues:
	Gathering and processing	$	—		$	—		$	71.1		$	—		$	71.1
	NGL and crude services	—			284.1			26.6			(3.4		)	307.3
	Storage and transportation	—			4.6			44.2			—			48.8
		—			288.7			141.9			(3.4		)	427.2
	Cost of product/services sold (excluding depreciation, amortization and accretion as shown below):
	Gathering and processing	—			—			12.9			—			12.9
	NGL and crude services	—			263.1			10.3			(3.4		)	270
	Storage and transportation	—			3.7			3.4			—			7.1
		—			266.8			26.6			(3.4		)	290
	Expenses:
	Operating and administrative	—			17.2			49.1			—			66.3
	Depreciation, amortization and accretion	—			21.4			34			—			55.4
	Other	—			—			(0.3		)	—			(0.3		)
	Operating income (loss)	—			(16.7		)	32.5			—			15.8
	Other income (expense):
	Interest and debt expense, net	(2.7		)	—			(20.1		)	—			(22.8		)
	Other	—			—			(0.4		)	—			(0.4		)
	Equity in net income of subsidiary	(5.1		)	—			—			5.1			—
	Income (loss) before income taxes	(7.8		)	(16.7		)	12			5.1			(7.4		)
	Provision for income taxes	0.1			0.1			0.3			—			0.5
	Net income (loss)	(7.9		)	(16.8		)	11.7			5.1			(7.9		)
	Net income attributable to non-controlling partners in subsidiaries	—			—			(0.4		)	—			(0.4		)
	Net income (loss) attributable to partners	$	(7.9	)	$	(16.8	)	$	11.3		$	5.1		$	(8.3	)
Condensed Consolidating Statements of Operations	'
	Condensed Consolidating Statements of Operations
	Three Months Ended September 30, 2013
	(in millions)
		Parent			Guarantor			Non-			Eliminations			Consolidated
					Subsidiaries			Guarantor
								Subsidiaries
	Revenues:
	Gathering and processing	$	—		$	—		$	71.1		$	—		$	71.1
	NGL and crude services	—			284.1			26.6			(3.4		)	307.3
	Storage and transportation	—			4.6			44.2			—			48.8
		—			288.7			141.9			(3.4		)	427.2
	Cost of product/services sold (excluding depreciation, amortization and accretion as shown below):
	Gathering and processing	—			—			12.9			—			12.9
	NGL and crude services	—			263.1			10.3			(3.4		)	270
	Storage and transportation	—			3.7			3.4			—			7.1
		—			266.8			26.6			(3.4		)	290
	Expenses:
	Operating and administrative	—			17.2			49.1			—			66.3
	Depreciation, amortization and accretion	—			21.4			34			—			55.4
	Other	—			—			(0.3		)	—			(0.3		)
	Operating income (loss)	—			(16.7		)	32.5			—			15.8
	Other income (expense):
	Interest and debt expense, net	(2.7		)	—			(20.1		)	—			(22.8		)
	Other	—			—			(0.4		)	—			(0.4		)
	Equity in net income of subsidiary	(5.1		)	—			—			5.1			—
	Income (loss) before income taxes	(7.8		)	(16.7		)	12			5.1			(7.4		)
	Provision for income taxes	0.1			0.1			0.3			—			0.5
	Net income (loss)	(7.9		)	(16.8		)	11.7			5.1			(7.9		)
	Net income attributable to non-controlling partners in subsidiaries	—			—			(0.4		)	—			(0.4		)
	Net income (loss) attributable to partners	$	(7.9	)	$	(16.8	)	$	11.3		$	5.1		$	(8.3	)
	Condensed Consolidating Statements of Operations
	Nine Months Ended September 30, 2013
	(in millions)
		Parent			Guarantor			Non-			Eliminations			Consolidated
					Subsidiaries			Guarantor
								Subsidiaries
	Revenues:
	Gathering and processing	$	—		$	—		$	214.6		$	—		$	214.6
	NGL and crude services	—			326			26.6			(3.8		)	348.8
	Storage and transportation	—			1.9			53.2						55.1
		—			327.9			294.4			(3.8		)	618.5
	Cost of product/services sold (excluding depreciation, amortization and accretion as shown below):
	Gathering and processing	—			—			40.4			—			40.4
	NGL and crude services	—			300.7			10.5			(3.8		)	307.4
	Storage and transportation	—			3.2			4.5						7.7
		—			303.9			55.4			(3.8		)	355.5
	Expenses:
	Operating and administrative	—			19.7			98.5			—			118.2
	Depreciation, amortization and accretion	—			23.5			82.3			—			105.8
	Other	—			—			(0.3		)	—			(0.3		)
	Operating income (loss)	—			(19.2		)	58.5			—			39.3
	Other income (expense):
	Interest and debt expense, net	(2.2		)	—			(44.0		)	—			(46.2		)
	Other	—			—			(0.4		)	—			(0.4		)
	Equity in net income of subsidiary	(6.2		)	—			—			6.2			—
	Income (loss) before income taxes	(8.4		)	(19.2		)	14.1			6.2			(7.3		)
	Provision for income taxes	0.1			0.1			1			—			1.2
	Net income (loss)	(8.5		)	(19.3		)	13.1			6.2			(8.5		)
	Net loss attributable to non-controlling partners in subsidiaries	—			—			6.9			—			6.9
	Net income (loss) attributable to partners	$	(8.5	)	$	(19.3	)	$	20		$	6.2		$	(1.6	)
Condensed Consolidating Statements of Comprehensive Income	'
	Condensed Consolidating Statements of Comprehensive Income
	Three Months Ended September 30, 2013
	(in millions)
		Parent			Guarantor			Non-			Eliminations			Consolidated
					Subsidiaries			Guarantor
								Subsidiaries
	Net income (loss)	$	(7.9	)	$	(16.8	)	$	11.7		$	5.1		$	(7.9	)
	Change in Suburban Propane Partners LP units	0.2			—			—			—			0.2
	Comprehensive income (loss)	$	(7.7	)	$	(16.8	)	$	11.7		$	5.1		$	(7.7	)
	Condensed Consolidating Statements of Comprehensive Income
	Nine Months Ended September 30, 2013
	(in millions)
		Parent			Guarantor			Non-			Eliminations			Consolidated
					Subsidiaries			Guarantor
								Subsidiaries
	Net income (loss)	$	(8.5	)	$	(19.3	)	$	13.1		$	6.2		$	(8.5	)
	Change in Suburban Propane Partners LP units	—			—			—			—			—
	Comprehensive income (loss)	$	(8.5	)	$	(19.3	)	$	13.1		$	6.2		$	(8.5	)
Condensed Consolidating Statements of Cash Flows	'
	Condensed Consolidating Statements of Cash Flows
	Nine Months Ended September 30, 2013
	(in millions)
		Parent			Guarantor			Non-			Eliminations			Consolidated
					Subsidiaries			Guarantor
								Subsidiaries
	Cash flows from operating activities	$	—		$	(14.0	)	$	128.1		$	—		$	114.1
	Cash flows from investing activities
	Acquisitions, net of cash acquired	0.1			5.1			0.9			—			6.1
	Purchases of property, plant and equipment	—			(9.7		)	(188.9		)	—			(198.6		)
	Investment in unconsolidated affiliate	—			—			(152.5		)	—			(152.5		)
	Other	—			0.1			11			—			11.1
	Net cash provided by (used in) investing activities	0.1			(4.5		)	(329.5		)	—			(333.9		)
	Cash flows from financing activities:
	Proceeds from the issuance of long-term debt	—			216.3			577.2			—			793.5
	Principal payments on long-term debt	—			(160.2		)	(568.5		)	—			(728.7		)
	Distributions paid	—			(28.9		)	(143.5		)	—			(172.4		)
	Distributions paid to non-controlling partners	—			—			(110.0		)	—			(110.0		)
	Net proceeds from the issuance of common units	—			—			356.7			—			356.7
	Proceeds from issuance of preferred equity	—			—			96.1			—			96.1
	Other	—			(6.9		)	0.2			—			(6.7		)
	Net cash provided by financing activities	—			20.3			208.2			—			228.5
	Net increase in cash	0.1			1.8			6.8			—			8.7
	Cash at beginning of period	—			—			0.1			—			0.1
	Cash at end of period	$	0.1		$	1.8		$	6.9		$	—		$	8.8

Partnership_Organization_and_B1

Partnership Organization and Basis of Presentation (Narrative) (Detail) (USD $)

0 Months Ended

9 Months Ended

0 Months Ended

0 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

0 Months Ended

In Millions, except Share data, unless otherwise specified

Jun. 19, 2013

Sep. 30, 2013

Jun. 05, 2013

Jun. 05, 2013

6-May-13

5-May-13

Oct. 07, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

6-May-13

Sep. 30, 2013

Jun. 19, 2013

6-May-13

segment

Common Units

Class D Units

CMLP

CMLP

CMLP

CMLP

CMLP

CMLP

CMLP

Inergy Midstream

Inergy Midstream

Inergy Midstream

Crestwood Holdings

Subsequent Event

First Distribution

Second Distribution

Third Distribution

All distributions above the third target

Unit Distribution

Partnership Organization And Basis Of Presentation [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive Distribution, Distribution Per Unit

'

'

'

'

'

'

$0.37

$0.35

$0.38

$0.45

'

'

$0.37

'

'

Incentive Distribution Rights, Percent

'

'

'

'

'

'

50.00%

1.80%

15.00%

25.00%

50.00%

'

50.00%

'

'

Business Combination, Equity Interest Issued or Issuable, Conversion Ratio

'

'

'

'

'

107.00%

'

'

'

'

'

'

'

'

'

Business Combination, Cash Payments to Unitholders Upon Completion of Merger

'

'

'

'

$35

'

'

'

'

'

'

$25

'

'

$10

Business Combination, Cash Payments to Unitholders Upon Completion of Merger, Per Unit

'

'

'

'

1.03

'

'

'

'

'

'

'

'

'

'

Distribution Made to Limited Partner, Unit Distribution

'

'

137,105

21,588

'

'

'

'

'

'

'

'

'

56,400,000

'

General partner ownership percentage

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Operating Segments

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Narrative) (Details) (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
	derivative	derivative	segment	derivative
			derivative
Summary Of Significant Accounting Policies [Line Items]	'	'	'	'	'
Derivative, Number of Instruments Held	0	0	0	0	'
Inventory (Note 3)	$95.70	'	$95.70	'	$0
Goodwill impairment	4.1	0	4.1	0	'
Percentage of gross income from qualifying sources required to be subject to federal income tax, minimum	'	'	90.00%	'	'
Construction in Progress Expenditures Incurred but Not yet Paid	'	'	47.4	'	9.2
Asset Retirement Obligations, Noncurrent	14.6	'	14.6	'	14
Unit-based compensation expense	'	'	7.6	1.5	'
Number of Operating Segments	'	'	3	'	'
Unit based compensation	'	'	'	'	'
Summary Of Significant Accounting Policies [Line Items]	'	'	'	'	'
Unit-based compensation expense	$5.60	$0.50	$7.60	$1.50	'
Texas | State and Local Jurisdiction	'	'	'	'	'
Summary Of Significant Accounting Policies [Line Items]	'	'	'	'	'
Effective Income Tax Rate Reconciliation, Other than Income Taxes, Statutory Income Tax Rate, Percent	'	'	0.70%	'	'

Summary_of_Significant_Account4

Summary of Significant Accounting Policies (Credit Risk and Concentrations) (Details)	3 Months Ended		9 Months Ended	3 Months Ended	9 Months Ended		12 Months Ended	3 Months Ended	12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2012
	Revenue	Revenue	Accounts Receivable	Quicksilver	Quicksilver	Quicksilver	Quicksilver	Antero	Antero
	Customer Concentration Risk	Customer Concentration Risk	Credit Concentration Risk	Revenue	Revenue	Revenue	Accounts Receivable	Revenue	Accounts Receivable
	customer	customer	customer	Customer Concentration Risk	Customer Concentration Risk	Customer Concentration Risk	Credit Concentration Risk	Customer Concentration Risk	Credit Concentration Risk
Concentration Risk [Line Items]	'	'	'	'	'	'	'	'	'
Concentration Risk, Number	0	2	0	'	'	'	'	'	'
Concentration Risk, Percentage	'	'	'	44.00%	12.00%	50.00%	48.00%	13.00%	14.00%

Summary_of_Significant_Account5

Summary of Significant Accounting Policies (Estimated Useful Lives Of Property, Plant And Equipment) (Detail)	9 Months Ended
	Sep. 30, 2013
Gathering systems | Minimum	'
Property, Plant and Equipment [Line Items]	'
Property, plant and equipment, useful life	'20 years
Gathering systems | Maximum	'
Property, Plant and Equipment [Line Items]	'
Property, plant and equipment, useful life	'20 years
Processing plants and compression facilities | Minimum	'
Property, Plant and Equipment [Line Items]	'
Property, plant and equipment, useful life	'20 years
Processing plants and compression facilities | Maximum	'
Property, Plant and Equipment [Line Items]	'
Property, plant and equipment, useful life	'25 years
Buildings, rights-of-way, and easements | Minimum	'
Property, Plant and Equipment [Line Items]	'
Property, plant and equipment, useful life	'20 years
Buildings, rights-of-way, and easements | Maximum	'
Property, Plant and Equipment [Line Items]	'
Property, plant and equipment, useful life	'70 years
Office furniture and equipment | Minimum	'
Property, Plant and Equipment [Line Items]	'
Property, plant and equipment, useful life	'5 years
Office furniture and equipment | 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
Pipelines | Minimum	'
Property, Plant and Equipment [Line Items]	'
Property, plant and equipment, useful life	'20 years
Pipelines | Maximum	'
Property, Plant and Equipment [Line Items]	'
Property, plant and equipment, useful life	'20 years
Base gas	'
Property, Plant and Equipment [Line Items]	'
Property, plant and equipment, useful life	'10 years

Summary_of_Significant_Account6

Summary of Significant Accounting Policies (Estimated Economic Lives Of Intangible Assets) (Detail)	9 Months Ended
	Sep. 30, 2013
Minimum | Covenants not to compete	'
Finite-Lived Intangible Assets [Line Items]	'
Intangible assets, weighted average useful life	'2 years
Minimum | Trademarks	'
Finite-Lived Intangible Assets [Line Items]	'
Intangible assets, weighted average useful life	'5 years
Minimum | Gathering and Processing Operations	'
Finite-Lived Intangible Assets [Line Items]	'
Intangible assets, weighted average useful life	'5 years
Maximum | Customer accounts	'
Finite-Lived Intangible Assets [Line Items]	'
Intangible assets, weighted average useful life	'10 years
Maximum | Covenants not to compete	'
Finite-Lived Intangible Assets [Line Items]	'
Intangible assets, weighted average useful life	'9 years
Maximum | Trademarks	'
Finite-Lived Intangible Assets [Line Items]	'
Intangible assets, weighted average useful life	'10 years
Maximum | Gathering and Processing Operations	'
Finite-Lived Intangible Assets [Line Items]	'
Intangible assets, weighted average useful life	'20 years

Summary_of_Significant_Account7

Summary of Significant Accounting Policies (Senior Notes) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Debt Instrument [Line Items]	'	'
Senior Notes	$11.50	$0
Notes Payable, Fair Value Disclosure	11.5	0
Nrgm Credit Facility	'	'
Debt Instrument [Line Items]	'	'
Senior Notes	500	0
Notes Payable, Fair Value Disclosure	497.8	0
CMLP | Senior Notes	'	'
Debt Instrument [Line Items]	'	'
Senior Notes	351.3	351.5
Notes Payable, Fair Value Disclosure	$369.30	$365.90

Certain_Balance_Sheet_Informat2

Certain Balance Sheet Information (Inventories) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Inventory [Line Items]	'	'
Inventory	$95.70	$0
NGLs	'	'
Inventory [Line Items]	'	'
Inventory	88.8	0
Parts, supplies and other	'	'
Inventory [Line Items]	'	'
Inventory	$6.90	$0

Certain_Balance_Sheet_Informat3

Certain Balance Sheet Information (Property, Plant And Equipment) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012
In Millions, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment	$3,727.90	$1,197.40	$1,129.80
Less: accumulated depreciation	167.8	95	'
Property, plant and equipment, net	3,560.10	1,102.40	'
Capital Leased Assets, Gross	11.5	11.8	'
Gathering systems	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment	662.5	582.3	'
Processing plants and compression facilities	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment	544.5	485.4	'
Plant equipment	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment	522.3	0	'
Buildings, rights-of-way, and easements	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment	75.2	66.4	'
Land and storage rights	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment	755.7	4.1	'
Pipelines	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment	661	0	'
Vehicles	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment	32.9	0.3	'
Construction in process	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment	246.6	56	'
Base gas	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment	97.9	0	'
Salt deposits	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment	120.5	0	'
Office furniture and equipment	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment	$8.80	$2.90	'

Certain_Balance_Sheet_Informat4

Certain Balance Sheet Information (Intangible Assets) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible assets, Gross	$1,098.90	$845.20
Less: accumulated amortization	84.8	49.9
Total intangible assets, net	1,014.10	795.3
Customer accounts	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible assets, Gross	231	0
Covenants not to compete	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible assets, Gross	7	0
Gas gathering, compression and processing contracts	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible assets, Gross	750.1	813
Acquired storage contracts	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible assets, Gross	43.5	0
Trademarks	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible assets, Gross	33.5	0
Deferred financing and other costs	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible assets, Gross	$33.80	$32.20

Business_Acquisitions_Narrativ

Business Acquisitions (Narrative) (Details) (USD $)

Sep. 30, 2013

Jun. 30, 2013

Jun. 19, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 24, 2013

Jul. 19, 2013

Jul. 19, 2013

Jun. 24, 2013

Jul. 19, 2013

Jul. 19, 2013

Sep. 30, 2013

In Millions, unless otherwise specified

Interest in Unidentified Entity [Member]

Interest in Unidentified Entity [Member]

Interest in Unidentified Entity [Member]

Interest in Unidentified Entity [Member]

Interest in Unidentified Entity [Member]

Interest in Unidentified Entity [Member]

Rangeland Energy, LLC

CMLP Credit Facility

Crestwood Niobrara LLC

Crestwood Niobrara LLC

Crestwood Niobrara LLC

Subsidiary Issuer

Capital Contributions Commitments

Maximum

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Percentage of Voting Interests Acquired

'

'

'

'

'

'

'

'

50.00%

'

'

'

Goodwill

$2,921.20

$2,100.10

[1]

$2,564.40

$352.20

$352.20

'

'

'

'

'

'

'

Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

2013

'

'

'

'

'

'

'

'

'

'

'

32.5

2014

'

'

'

'

'

'

'

'

'

'

'

51.2

2015

'

'

'

'

'

'

'

'

'

'

'

43.7

2016

'

'

'

'

'

'

'

'

'

'

'

35.8

2017

'

'

'

'

'

'

'

'

'

'

'

31.5

Business Combination, Consideration Transferred

'

'

'

'

'

107.5

'

'

'

'

'

'

Debt Instrument, Increase, Additional Borrowings

'

'

'

'

'

'

26.9

'

'

'

'

'

Other Significant Noncash Transaction, Value of Consideration Received

'

'

'

'

'

'

'

'

'

'

80.6

'

Other Commitment, Percentage of Contributions

'

'

'

'

'

'

'

75.00%

'

'

'

'

Other Commitment

'

'

'

'

'

'

'

'

'

$69.40

'

'

[1]

Provisional amount recorded as of June 30, 2013.

Business_Acquisitions_Assets_A

Business Acquisitions (Assets Acquired, Liabilities Assumed) (Details) (USD $)	Sep. 30, 2013	Jun. 30, 2013		Jun. 19, 2013	Dec. 31, 2012	Sep. 30, 2012
In Millions, unless otherwise specified
Change in Accounting Estimate [Line Items]	'	'		'	'	'
Current assets	'	$222.70	[1]	$222.70	'	'
Property, plant and equipment	'	2,554.90	[1]	2,259.70	'	'
Intangible assets	'	273	[1]	315	'	'
Other assets	'	51.2	[1]	12.7	'	'
Total identifiable assets acquired	'	3,101.80	[1]	2,810.10	'	'
Current liabilities	'	205.5	[1]	208.9	'	'
Long-term debt	'	1,079.30	[1]	1,079.30	'	'
Other long-term liabilities	'	43.9	[1]	213.1	'	'
Total liabilities assumed	'	1,328.70	[1]	1,501.30	'	'
Net identifiable assets acquired	'	1,773.10	[1]	1,308.80	'	'
Goodwill	2,921.20	2,100.10	[1]	2,564.40	352.2	352.2
Net assets acquired	'	3,873.20	[1]	3,873.20	'	'
Purchase Price Allocation Adjustments [Member]	'	'		'	'	'
Change in Accounting Estimate [Line Items]	'	'		'	'	'
Current assets	'	0		'	'	'
Property, plant and equipment	'	-295.2		'	'	'
Intangible assets	'	42		'	'	'
Other assets	'	-38.5		'	'	'
Total identifiable assets acquired	'	-291.7		'	'	'
Current liabilities	'	3.4		'	'	'
Long-term debt	'	0		'	'	'
Other long-term liabilities	'	169.2		'	'	'
Total liabilities assumed	'	172.6		'	'	'
Net identifiable assets acquired	'	-464.3		'	'	'
Goodwill	'	464.3		'	'	'
Net assets acquired	'	$0		'	'	'
[1]	Provisional amount recorded as of June 30, 2013.

Business_Acquisitions_Pro_Form

Business Acquisitions (Pro Forma Revenues) (Details) (Rangeland Energy, LLC, USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2012		Sep. 30, 2013	Sep. 30, 2012
Rangeland Energy, LLC	'		'	'
Business Acquisition [Line Items]	'		'	'
Revenue	$333.70	[1]	$1,339.90	$1,026.40	[1]
Net income (loss)	$73.20	[1]	($34.20)	$105.10	[1]
Earnings Per Share, Basic	$1.90	[1]	($0.33)	$2.42	[1]
Earnings Per Share, Diluted	$1.69	[1]	($0.33)	$2.15	[1]
[1]	The three-month and nine-month periods ended September 30, 2012 have also been adjusted to reflect the contribution of the Company's retail operations to Suburban Propane Partners on August 1, 2012 as if that contribution had been removed from the consolidated results of operations at the beginning of each period presented.

Fair_Value_Measurements_Assets

Fair Value Measurements (Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) (USD $)	Sep. 30, 2013
In Millions, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Assets from price risk management	$23.70
SPH units	6.6
Total assets at fair value	30.3
Liabilities from price risk management	31.9
Interest rate swaps	4.8
Total liabilities at fair value	36.7
Level 1	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Assets from price risk management	0.3
SPH units	6.6
Total assets at fair value	6.9
Liabilities from price risk management	0.3
Interest rate swaps	0
Total liabilities at fair value	0.3
Level 2	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Assets from price risk management	35.9
SPH units	0
Total assets at fair value	35.9
Liabilities from price risk management	29.7
Interest rate swaps	4.8
Total liabilities at fair value	34.5
Level 3	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Assets from price risk management	0
SPH units	0
Total assets at fair value	0
Liabilities from price risk management	0
Interest rate swaps	0
Total liabilities at fair value	0
Total	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Assets from price risk management	36.2
SPH units	6.6
Total assets at fair value	42.8
Liabilities from price risk management	30
Interest rate swaps	4.8
Total liabilities at fair value	34.8
Designated as Hedges	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Assets from price risk management	0
SPH units	0
Total assets at fair value	0
Liabilities from price risk management	0
Interest rate swaps	0
Total liabilities at fair value	0
Not Designated as Hedges	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Assets from price risk management	36.2
SPH units	6.6
Total assets at fair value	42.8
Liabilities from price risk management	30
Interest rate swaps	4.8
Total liabilities at fair value	34.8
Netting Agreements	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Assets from price risk management	-12.5	[1]
SPH units	0	[1]
Total assets at fair value	-12.5	[1]
Liabilities from price risk management	1.9	[1]
Interest rate swaps	0	[1]
Total liabilities at fair value	$1.90	[1]
[1]	Amounts represent the impact of legally enforceable master netting agreements that allow the Company to settle positive and negative positions as well as cash collateral held or placed with the same counterparties.

Risk_Management_Notional_Amoun

Risk Management (Notional Amounts and Terms of Company's Derivative Financial Instruments) (Details)	Sep. 30, 2013	Dec. 31, 2012
	bbl	bbl
Fixed Price Payor	'	'
Derivative [Line Items]	'	'
Propane, crude and heating oil (barrels)	7,200,000	0
Fixed Price Receiver	'	'
Derivative [Line Items]	'	'
Propane, crude and heating oil (barrels)	8,800,000	0

Risk_Management_Narrative_Deta

Risk Management (Narrative) (Details) (USD $)	9 Months Ended
	Sep. 30, 2013
Derivative [Line Items]	'
Collateral posted for commodity derivative instruments	10,200,000
Commodity contract	'
Derivative [Line Items]	'
Aggregate fair value of commodity derivative instruments	12,100,000
Collateral posted for commodity derivative instruments	1,500,000
NYMEX margin deposit	'
Derivative [Line Items]	'
NYMEX margin deposit	5,200,000
Price Risk Contracts | Maximum	'
Derivative [Line Items]	'
Derivative, Remaining Maturity	'34 months
Derivative Contracts, Contracts Expiring in Next Twleve Months, Percent	95.90%

LongTerm_Debt_Components_Of_Lo

Long-Term Debt (Components Of Long-Term Debt) (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Jun. 30, 2013

Sep. 30, 2013

In Millions, unless otherwise specified

Revolving Loan Facility

Revolving Loan Facility

CMLP

CMLP

Nrgm Credit Facility

Nrgm Credit Facility

CMM Credit Facility

CMM Credit Facility

Credit Agreement

Credit Agreement

Revolving Loan Facility

Revolving Loan Facility

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Consolidated Ebitda To Consolidated Interest Expense

'

'

'

'

'

'

'

'

'

'

1

10.2

Credit agreement outstanding carrying value

'

'

$376.20

$0

$356.20

$206.70

$37

$0

$191.90

$127

'

'

Senior Notes

11.5

0

'

'

350

350

500

0

'

'

'

'

Obligations under noncompetition agreements and notes to former owners of businesses acquired

2.9

0

'

'

'

'

'

'

'

'

'

'

Premium on senior notes

'

'

'

'

1.3

1.5

'

'

'

'

'

'

Liabilities, Fair Value Adjustment

'

'

'

'

'

'

4.8

0

'

'

'

'

Total debt

1,831.80

685.2

'

'

'

'

'

'

'

'

'

'

Current portion of long-term debt (Note 7)

4.4

0

'

'

'

'

'

'

'

'

'

'

Total long-term debt

$1,827.40

$685.20

'

'

'

'

'

'

'

'

'

'

LongTerm_Debt_Narrative_Detail

Long-Term Debt (Narrative) (Detail) (USD $)

9 Months Ended

9 Months Ended

6 Months Ended

9 Months Ended

6 Months Ended

6 Months Ended

9 Months Ended

9 Months Ended

0 Months Ended

Sep. 30, 2013

Sep. 30, 2012

22-May-13

Dec. 31, 2012

Dec. 07, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Jun. 30, 2013

Sep. 30, 2013

Jun. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Jun. 30, 2013

Sep. 30, 2013

Apr. 13, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Nov. 08, 2012

Apr. 02, 2011

Sep. 30, 2013

Dec. 31, 2012

Oct. 07, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Inergy Midstream

Inergy Midstream

CMLP

CMLP

Credit Agreement

Credit Agreement

Minimum

Maximum

Maximum

Maximum

Maximum

Revolving Loan Facility

Revolving Loan Facility

Revolving Loan Facility

Revolving Loan Facility

Revolving Loan Facility

Revolving Loan Facility

Revolving Loan Facility

Revolving Loan Facility

Term Loan Facility

Nrgm Credit Facility

CMLP Credit Facility

CMLP Credit Facility

CMLP Credit Facility

CMLP Credit Facility

CMLP

CMLP

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Revolving Loan Facility

Revolving Loan Facility

Revolving Loan Facility

Revolving Loan Facility

Revolving Loan Facility

Nrgm Credit Facility

Nrgm Credit Facility

Credit Agreement

LIBO Rate

LIBO Rate

Credit Agreement

Credit Agreement

Amended and Restated

Credit Agreement

Minimum

Minimum

Minimum

Maximum

Maximum

Maximum

Interest Rate Swaps Accounted For As Cash Flow Hedges

Maximum

Maximum

CMLP

CMLP

CMLP Senior Notes

CMLP Senior Notes

CMLP

CMM Credit Facility

CMM Credit Facility

LIBO Rate, Adjustment

LIBO Rate

Credit Agreement

Credit Agreement

LIBO Rate

Credit Agreement

Credit Agreement

Interest Rate Swaps Maturing 2015

LIBO Rate

LIBO Rate

Subsequent Event

LIBO Rate

Adjusted LIBO Rate

LIBO Rate

Adjusted LIBO Rate

derivative

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit agreement outstanding carrying value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$550,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,000,000,000

'

'

'

'

Debt Instrument, Interest Rate, Basis for Effective Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'0.005

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Variable interest rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.00%

'

0.75%

1.75%

'

2.00%

3.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit agreement outstanding carrying value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

356,200,000

206,700,000

'

'

'

'

376,200,000

0

623,600,000

191,900,000

127,000,000

37,000,000

0

Line of Credit Facility, Interest Rate at Period End

'

'

'

'

'

'

'

'

'

'

'

'

2.80%

2.50%

'

'

'

'

2.69%

'

'

4.75%

'

'

'

'

'

'

2.80%

2.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit Agreement amount available

'

'

'

'

'

'

'

'

'

'

122,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letters of credit outstanding

'

'

'

'

'

'

'

'

'

'

51,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Funded Debt to Consolidated Ebitda

'

'

'

'

'

'

'

'

'

'

'

1

'

'

4.75

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consolidated Ebitda To Consolidated Interest Expense

'

'

'

'

'

'

'

'

'

1

10.2

2.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior Secured Funded Debt To Consolidated Ebitda As Defined In Credit Agreement

'

'

'

'

'

'

'

'

'

'

4.3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayments of Long-term Debt

160,200,000

0

'

'

'

299,500,000

0

194,000,000

329,500,000

'

'

'

'

'

'

300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of interest rate swaps entered during period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fixed rate, range low end

0.84%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fixed rate, range high end

2.52%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate notional amount, cash flow hedges

225,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior Notes

11,500,000

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

350,000,000

350,000,000

351,300,000

351,500,000

150,000,000

200,000,000

'

'

'

'

'

500,000,000

0

Line of Credit Facility, Expiration Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

Debt, Weighted Average Interest Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.00%

2.80%

'

'

'

'

'

'

'

'

'

'

'

3.00%

2.80%

'

'

Debt Instrument, Interest Rate, Stated Percentage

7.00%

'

'

'

6.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7.75%

'

'

'

'

'

'

'

Long-term Debt, Fair Value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,800,000

0

Debt Instruments, Covenant Compliance, Consent Soliciations, Consents Not Revoked, Value

'

'

$464,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instruments, Covenant Compliance, Consent Soliciations, Consents Not Revoked, Percent

'

'

92.90%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners_Capital_Narrative_Det

Partners' Capital (Narrative) (Details) (USD $)

0 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

9 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

In Millions, except Share data, unless otherwise specified

Jun. 19, 2013

Apr. 05, 2013

Sep. 30, 2013

Sep. 30, 2012

Apr. 05, 2013

Mar. 22, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 13, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Oct. 07, 2013

Sep. 30, 2013

Mar. 31, 2013

Sep. 30, 2013

Jan. 31, 2013

Jun. 30, 2013

Mar. 31, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Jul. 19, 2013

CMLP

CMLP

CMLP

CMLP

CMLP

CMLP

Inergy Midstream

Inergy Midstream

Inergy Midstream

Inergy Midstream

Inergy Midstream

Class C Units

Class C Units

Class D Units

Class D Units

Class D Units

Class D Units

Non-Controlling Partners

Non-Controlling Partners

Non-Controlling Partners

Non-Controlling Partners

Non-Controlling Partners

Interest in Unidentified Entity [Member]

Limited Partner [Member]

Limited Partner [Member]

Limited Partner [Member]

Limited Partner [Member]

Subsequent Event

CMLP

CMLP

CMLP

Inergy Midstream

Class C Units

Class D Units

Subsidiary Issuer

Distribution Made to Member or Limited Partner [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Significant Noncash Transaction, Value of Consideration Received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$80.60

Proceeds from issuance of preferred equity of subsidiary, net

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

96.1

96.1

'

'

'

'

Proceeds from Noncontrolling Interests, Initial Contribution

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

80.7

80.6

'

'

'

'

Proceeds from Noncontrolling Interests, Additional Capital Contributions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15.4

15.5

'

'

'

'

Units sold in public offering

'

'

'

'

'

4,500,000

'

'

'

'

11,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Price per unit, gross

'

'

'

'

'

23.9

'

'

'

'

21.69

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Price per unit, net

'

'

'

'

'

23

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds from issuance of Inergy Midstream, L.P. common units

'

'

'

'

'

'

'

'

'

'

238.4

'

238.2

0

'

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds from public offering

'

'

'

'

15.5

103.5

'

'

'

'

'

'

356.7

'

'

0

'

0

'

'

'

'

'

356.7

-0.6

126.3

'

Partners' Capital Account, Period Underwriters May Option to Purchase Additional Units

'

'

'

'

'

'30 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Undewriters option for additional units

'

675,000

'

'

'

'

'

'

'

'

'

'

'

'

773,191

'

'

'

'

'

'

'

'

'

'

'

'

Convertible Units, Units Issued upon Conversion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

Distribution Made to Member or Limited Partner, Share Distribution

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,190,469

141,422

151,238

'

'

'

'

'

'

General partner ownership percentage

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

65.00%

'

'

'

'

'

'

'

'

Distribution Made to Member or Limited Partner, Cash Distributions Paid

'

'

$22.30

'

'

'

$27.40

$20.60

$75.80

$56.70

'

$34.20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Sep. 23, 2011	Jun. 30, 2010	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013
			Marc I Pipeline	Marc I Pipeline	Class Action Challenging Crestwood Merger	Class Action Challenging Crestwood Merger - Federal	Watkins Glen Ngl Development Project	Identified Growth Projects	Other Growth and Maintenance Contractual Purchase Obligations	Commodity
			Anadarko	Anadarko	Lawsuit	Lawsuit	bbl
Purchase Commitment, Excluding Long-term Commitment [Line Items]	'	'	'	'	'	'	'	'	'	'
Firm Purchase Commitments	'	'	'	'	'	'	'	$52,000,000	$43,300,000	$275,000,000
Estimated Percentage Of Purchase Commitments Occur Within One Year	'	'	'	'	'	'	'	'	'	97.60%
Storage capacity barrels	'	'	'	'	'	'	2,100,000	'	'	'
Capital Lease Obligations	4,200,000	7,000,000	'	'	'	'	'	'	'	'
Number of putative class action lawsuits	'	'	'	'	5	4	'	'	'	'
Counterparty Option To Purchase Maximum Ownership Interest	'	'	25.00%	25.00%	'	'	'	'	'	'
Accrued Liabilities, Environmental Compliance	300,000	200,000	'	'	'	'	'	'	'	'
Loss Contingency, Range of Possible Loss, Minimum	300,000	'	'	'	'	'	'	'	'	'
Loss Contingency, Range of Possible Loss, Maximum	500,000	'	'	'	'	'	'	'	'	'
Self-insurance reserves	17,000,000	0	'	'	'	'	'	'	'	'
Self-insurance reserve expected to be paid in next fiscal year	$12,200,000	'	'	'	'	'	'	'	'	'

Segments_Reconciliation_of_Net

Segments (Reconciliation of Net Income (Loss) to EBITDA) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Segment Reporting [Abstract]	'	'	'	'
Net income (loss)	($7.90)	$9.10	($8.50)	$21.90
Interest and debt expense, net	22.8	8.9	46.2	25.4
Provision for income taxes	0.5	0.3	1.2	0.9
Depreciation, amortization and accretion	55.4	16.9	105.8	51.9
EBITDA	$70.80	$35.20	$144.70	$100.10

Segments_Summary_Of_Segment_In

Segments (Summary Of Segment Information) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Jun. 30, 2013		Jun. 19, 2013	Dec. 31, 2012
			segment
Number of Operating Segments	'	'	3	'	'		'	'
Operating revenues	$427.20	$63	$618.50	$172	'		'	'
Cost of product/services sold	290	10.3	355.5	26.7	'		'	'
Operating and administrative	66.3	17.5	118.2	52	'		'	'
Gain on contingent consideration	0	0	0	6.8	'		'	'
Goodwill impairment	-4.1	0	-4.1	0	'		'	'
Gain on sale of assets	4.4	0	4.4	0	'		'	'
Loss from unconsolidated affiliate	-0.4	0	-0.4	0	'		'	'
EBITDA	70.8	35.2	144.7	100.1	'		'	'
Identifiable assets	334.6	39.5	334.6	39.5	'		'	'
Goodwill	2,921.20	352.2	2,921.20	352.2	2,100.10	[1]	2,564.40	352.2
Property, plant and equipment	3,727.90	1,129.80	3,727.90	1,129.80	'		'	1,197.40
Cash expenditures for property, plant and equipment	114.5	11.9	198.6	34.3	'		'	'
Gathering and Processing Operations	'	'	'	'	'		'	'
Operating revenues	71.1	63	214.6	172	'		'	'
Cost of product/services sold	12.9	10.3	40.4	26.7	'		'	'
Operating and administrative	14.9	10.9	40.5	30	'		'	'
Gain on contingent consideration	'	'	'	6.8	'		'	'
Goodwill impairment	-4.1	'	-4.1	'	'		'	'
Gain on sale of assets	4.4	'	4.4	'	'		'	'
Loss from unconsolidated affiliate	-0.4	'	-0.4	'	'		'	'
EBITDA	43.2	41.8	133.6	122.1	'		'	'
Identifiable assets	51.7	39.5	51.7	39.5	'		'	'
Goodwill	356.8	352.2	356.8	352.2	'		'	'
Property, plant and equipment	1,440.90	1,129.80	1,440.90	1,129.80	'		'	'
Cash expenditures for property, plant and equipment	84.2	11.9	164.5	34.3	'		'	'
NGL and Crude Services Operations	'	'	'	'	'		'	'
Operating revenues	307.3	0	348.8	0	'		'	'
Cost of product/services sold	270	0	307.4	0	'		'	'
Operating and administrative	15.5	0	17.3	0	'		'	'
Gain on contingent consideration	'	'	'	0	'		'	'
Goodwill impairment	0	'	0	'	'		'	'
Gain on sale of assets	0	'	0	'	'		'	'
Loss from unconsolidated affiliate	0	'	0	'	'		'	'
EBITDA	21.8	0	24.1	0	'		'	'
Identifiable assets	267	0	267	0	'		'	'
Goodwill	1,430.80	0	1,430.80	0	'		'	'
Property, plant and equipment	693.7	0	693.7	0	'		'	'
Cash expenditures for property, plant and equipment	17.9	0	19.1	0	'		'	'
Storage and Transportation Operations	'	'	'	'	'		'	'
Operating revenues	48.8	0	55.1	0	'		'	'
Cost of product/services sold	7.1	0	7.7	0	'		'	'
Operating and administrative	6.8	0	7.7	0	'		'	'
Gain on contingent consideration	'	'	'	0	'		'	'
Goodwill impairment	0	'	0	'	'		'	'
Gain on sale of assets	0	'	0	'	'		'	'
Loss from unconsolidated affiliate	0	'	0	'	'		'	'
EBITDA	34.9	0	39.7	0	'		'	'
Identifiable assets	18.7	0	18.7	0	'		'	'
Goodwill	1,133.60	0	1,133.60	0	'		'	'
Property, plant and equipment	1,590.80	0	1,590.80	0	'		'	'
Cash expenditures for property, plant and equipment	12.4	0	15	0	'		'	'
Intersegment Operations	'	'	'	'	'		'	'
Operating revenues	0	0	0	0	'		'	'
Cost of product/services sold	0	0	0	0	'		'	'
Operating and administrative	0	0	0	0	'		'	'
Gain on contingent consideration	'	'	'	0	'		'	'
Goodwill impairment	0	'	0	'	'		'	'
Gain on sale of assets	0	'	0	'	'		'	'
Loss from unconsolidated affiliate	0	'	0	'	'		'	'
EBITDA	0	0	0	0	'		'	'
Identifiable assets	-2.8	0	-2.8	0	'		'	'
Goodwill	0	0	0	0	'		'	'
Property, plant and equipment	0	0	0	0	'		'	'
Cash expenditures for property, plant and equipment	0	0	0	0	'		'	'
Corporate Operations	'	'	'	'	'		'	'
Operating revenues	0	0	0	0	'		'	'
Cost of product/services sold	0	0	0	0	'		'	'
Operating and administrative	29.1	6.6	52.7	22	'		'	'
Gain on contingent consideration	'	'	'	0	'		'	'
Goodwill impairment	0	'	0	'	'		'	'
Gain on sale of assets	0	'	0	'	'		'	'
Loss from unconsolidated affiliate	0	'	0	'	'		'	'
EBITDA	-29.1	-6.6	-52.7	-22	'		'	'
Identifiable assets	0	0	0	0	'		'	'
Goodwill	0	0	0	0	'		'	'
Property, plant and equipment	2.5	0	2.5	0	'		'	'
Cash expenditures for property, plant and equipment	$0	$0	$0	$0	'		'	'
[1]	Provisional amount recorded as of June 30, 2013.

Related_Party_Transactions_Det

Related Party Transactions (Details) (Affiliated Entity, USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Affiliated Entity	'	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'	'
Gathering and processing revenues	$24.10	$27.90	$74.30	$86.70	'
Gathering and processing cost of goods sold	7.6	0	22.2	0	'
Operating and administrative expense	6.1	5.1	17.2	14.6	'
Reimbursements	0.2	0.2	0.7	0.7	'
Related Party Transaction, Due from (to) Related Party [Abstract]	'	'	'	'	'
Accounts receivable	22.1	'	22.1	'	23.8
Accounts payable	$6.20	'	$6.20	'	$3.10

Condensed_Consolidating_Financ2

Condensed Consolidating Financial Information (Condensed Consolidating Balance Sheet) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
Current assets:	'	'	'	'
Cash and cash equivalents	$8.80	$0.10	$0.10	$0.80
Accounts receivable	238.9	45.4	'	'
Inventory	95.7	0	'	'
Total current assets	387.2	50.4	'	'
Property, plant and equipment, net	3,560.10	1,102.40	'	'
Other assets	15.7	1.3	'	'
Total assets	8,050.40	2,301.60	'	'
Current liabilities:	'	'	'	'
Accounts payable	212.1	5.4	'	'
Total current liabilities	396.9	48.5	'	'
Long-term liabilities:	'	'	'	'
Long-term debt, less current portion (Note 7)	1,827.40	685.2	'	'
Other long-term liabilities	204.8	17.2	'	'
Partners' capital	1,367.80	31.7	'	'
Interest of non-controlling partners in subsidiary	4,236.10	1,519	'	'
Total partners’ capital	5,603.90	1,550.70	'	'
Total liabilities and partners’ capital	8,050.40	2,301.60	'	'
Parent Company	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	0.1	0	'	'
Accounts receivable	0	'	'	'
Inventory	0	'	'	'
Other	0	'	'	'
Total current assets	0.1	'	'	'
Property, plant and equipment, net	0	'	'	'
Goodwill and intangible assets, net	0	'	'	'
Investment in subsidiary	1,784.20	'	'	'
Other assets	0	'	'	'
Total assets	1,784.30	'	'	'
Current liabilities:	'	'	'	'
Accounts payable	0	'	'	'
Other current liabilities	8.1	'	'	'
Total current liabilities	8.1	'	'	'
Long-term liabilities:	'	'	'	'
Long-term debt, less current portion (Note 7)	386.1	'	'	'
Other long-term liabilities	22.3	'	'	'
Total long-term liabilities	408.4	'	'	'
Partners' capital	1,367.80	'	'	'
Interest of non-controlling partners in subsidiary	0	'	'	'
Total partners’ capital	1,367.80	'	'	'
Total liabilities and partners’ capital	1,784.30	'	'	'
Guarantor Subsidiaries	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	1.8	0	'	'
Accounts receivable	163.7	'	'	'
Inventory	89.8	'	'	'
Other	27.6	'	'	'
Total current assets	282.9	'	'	'
Property, plant and equipment, net	572.9	'	'	'
Goodwill and intangible assets, net	1,346.80	'	'	'
Investment in subsidiary	0	'	'	'
Other assets	10.3	'	'	'
Total assets	2,212.90	'	'	'
Current liabilities:	'	'	'	'
Accounts payable	192.4	'	'	'
Other current liabilities	74.3	'	'	'
Total current liabilities	266.7	'	'	'
Long-term liabilities:	'	'	'	'
Long-term debt, less current portion (Note 7)	0	'	'	'
Other long-term liabilities	178.7	'	'	'
Total long-term liabilities	178.7	'	'	'
Partners' capital	1,767.50	'	'	'
Interest of non-controlling partners in subsidiary	0	'	'	'
Total partners’ capital	1,767.50	'	'	'
Total liabilities and partners’ capital	2,212.90	'	'	'
Non-Guarantor Subsidiaries	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	6.9	0.1	'	'
Accounts receivable	78	'	'	'
Inventory	5.9	'	'	'
Other	17.2	'	'	'
Total current assets	108	'	'	'
Property, plant and equipment, net	2,987.20	'	'	'
Goodwill and intangible assets, net	2,588.50	'	'	'
Investment in subsidiary	0	'	'	'
Other assets	157.5	'	'	'
Total assets	5,841.20	'	'	'
Current liabilities:	'	'	'	'
Accounts payable	20.5	'	'	'
Other current liabilities	105.4	'	'	'
Total current liabilities	125.9	'	'	'
Long-term liabilities:	'	'	'	'
Long-term debt, less current portion (Note 7)	1,441.30	'	'	'
Other long-term liabilities	21.2	'	'	'
Total long-term liabilities	1,462.50	'	'	'
Partners' capital	16.7	'	'	'
Interest of non-controlling partners in subsidiary	4,236.10	'	'	'
Total partners’ capital	4,252.80	'	'	'
Total liabilities and partners’ capital	5,841.20	'	'	'
Consolidation, Eliminations	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	0	0	'	'
Accounts receivable	-2.8	'	'	'
Inventory	0	'	'	'
Other	-1	'	'	'
Total current assets	-3.8	'	'	'
Property, plant and equipment, net	0	'	'	'
Goodwill and intangible assets, net	0	'	'	'
Investment in subsidiary	-1,784.20	'	'	'
Other assets	0	'	'	'
Total assets	-1,788	'	'	'
Current liabilities:	'	'	'	'
Accounts payable	-0.8	'	'	'
Other current liabilities	-3	'	'	'
Total current liabilities	-3.8	'	'	'
Long-term liabilities:	'	'	'	'
Long-term debt, less current portion (Note 7)	0	'	'	'
Other long-term liabilities	0	'	'	'
Total long-term liabilities	0	'	'	'
Partners' capital	-1,784.20	'	'	'
Interest of non-controlling partners in subsidiary	0	'	'	'
Total partners’ capital	-1,784.20	'	'	'
Total liabilities and partners’ capital	-1,788	'	'	'
Consolidated Entities	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	8.8	0.1	'	'
Accounts receivable	238.9	'	'	'
Inventory	95.7	'	'	'
Other	43.8	'	'	'
Total current assets	387.2	'	'	'
Property, plant and equipment, net	3,560.10	'	'	'
Goodwill and intangible assets, net	3,935.30	'	'	'
Investment in subsidiary	0	'	'	'
Other assets	167.8	'	'	'
Total assets	8,050.40	'	'	'
Current liabilities:	'	'	'	'
Accounts payable	212.1	'	'	'
Other current liabilities	184.8	'	'	'
Total current liabilities	396.9	'	'	'
Long-term liabilities:	'	'	'	'
Long-term debt, less current portion (Note 7)	1,827.40	'	'	'
Other long-term liabilities	222.2	'	'	'
Total long-term liabilities	2,049.60	'	'	'
Partners' capital	1,367.80	'	'	'
Interest of non-controlling partners in subsidiary	4,236.10	'	'	'
Total partners’ capital	5,603.90	'	'	'
Total liabilities and partners’ capital	$8,050.40	'	'	'

Condensed_Consolidating_Financ3

Condensed Consolidating Financial Information (Condensed Consolidating Statements Of Operations) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Revenues:	'	'	'	'
Gathering and processing	$71.10	$63	$214.60	$172
Total revenue	427.2	63	618.5	172
Cost of product/services sold (excluding depreciation, amortization and accretion as shown below):	'	'	'	'
Gathering and processing	12.9	10.3	40.4	26.7
Cost of product/services sold	290	10.3	355.5	26.7
Expenses:	'	'	'	'
Operating and administrative	66.3	17.5	118.2	52
Depreciation, amortization and accretion	55.4	16.9	105.8	51.9
Operating income	15.8	18.3	39.3	48.2
Other income (expense):	'	'	'	'
Income (loss) before income taxes	-7.4	9.4	-7.3	22.8
Provision for income taxes	0.5	0.3	1.2	0.9
Net income (loss)	-7.9	9.1	-8.5	21.9
Net income attributable to non-controlling partners in subsidiary	-0.4	-3.1	6.9	-9.2
Net income (loss) attributable to Crestwood Equity Partners LP	-8.3	6	-1.6	12.7
Parent Company	'	'	'	'
Revenues:	'	'	'	'
Gathering and processing	0	'	0	'
NGL and crude services	0	'	0	'
Storage and transportation	0	'	0	'
Total revenue	0	'	0	'
Cost of product/services sold (excluding depreciation, amortization and accretion as shown below):	'	'	'	'
Gathering and processing	0	'	0	'
NGL and crude services	0	'	0	'
Storage and transportation	0	'	0	'
Cost of product/services sold	0	'	0	'
Expenses:	'	'	'	'
Operating and administrative	0	'	0	'
Depreciation, amortization and accretion	0	'	0	'
Other	0	'	0	'
Operating income	0	'	0	'
Other income (expense):	'	'	'	'
Interest and debt expense, net	-2.7	'	-2.2	'
Other	0	'	0	'
Equity in net income of subsidiary	-5.1	'	-6.2	'
Income (loss) before income taxes	-7.8	'	-8.4	'
Provision for income taxes	0.1	'	0.1	'
Net income (loss)	-7.9	'	-8.5	'
Net income attributable to non-controlling partners in subsidiary	0	'	0	'
Net income (loss) attributable to Crestwood Equity Partners LP	-7.9	'	-8.5	'
Guarantor Subsidiaries	'	'	'	'
Revenues:	'	'	'	'
Gathering and processing	0	'	0	'
NGL and crude services	284.1	'	326	'
Storage and transportation	4.6	'	1.9	'
Total revenue	288.7	'	327.9	'
Cost of product/services sold (excluding depreciation, amortization and accretion as shown below):	'	'	'	'
Gathering and processing	0	'	0	'
NGL and crude services	263.1	'	300.7	'
Storage and transportation	3.7	'	3.2	'
Cost of product/services sold	266.8	'	303.9	'
Expenses:	'	'	'	'
Operating and administrative	17.2	'	19.7	'
Depreciation, amortization and accretion	21.4	'	23.5	'
Other	0	'	0	'
Operating income	-16.7	'	-19.2	'
Other income (expense):	'	'	'	'
Interest and debt expense, net	0	'	0	'
Other	0	'	0	'
Equity in net income of subsidiary	0	'	0	'
Income (loss) before income taxes	-16.7	'	-19.2	'
Provision for income taxes	0.1	'	0.1	'
Net income (loss)	-16.8	'	-19.3	'
Net income attributable to non-controlling partners in subsidiary	0	'	0	'
Net income (loss) attributable to Crestwood Equity Partners LP	-16.8	'	-19.3	'
Non-Guarantor Subsidiaries	'	'	'	'
Revenues:	'	'	'	'
Gathering and processing	71.1	'	214.6	'
NGL and crude services	26.6	'	26.6	'
Storage and transportation	44.2	'	53.2	'
Total revenue	141.9	'	294.4	'
Cost of product/services sold (excluding depreciation, amortization and accretion as shown below):	'	'	'	'
Gathering and processing	12.9	'	40.4	'
NGL and crude services	10.3	'	10.5	'
Storage and transportation	3.4	'	4.5	'
Cost of product/services sold	26.6	'	55.4	'
Expenses:	'	'	'	'
Operating and administrative	49.1	'	98.5	'
Depreciation, amortization and accretion	34	'	82.3	'
Other	-0.3	'	-0.3	'
Operating income	32.5	'	58.5	'
Other income (expense):	'	'	'	'
Interest and debt expense, net	-20.1	'	-44	'
Other	-0.4	'	-0.4	'
Equity in net income of subsidiary	0	'	0	'
Income (loss) before income taxes	12	'	14.1	'
Provision for income taxes	0.3	'	1	'
Net income (loss)	11.7	'	13.1	'
Net income attributable to non-controlling partners in subsidiary	-0.4	'	6.9	'
Net income (loss) attributable to Crestwood Equity Partners LP	11.3	'	20	'
Consolidation, Eliminations	'	'	'	'
Revenues:	'	'	'	'
Gathering and processing	0	'	0	'
NGL and crude services	-3.4	'	-3.8	'
Storage and transportation	0	'	'	'
Total revenue	-3.4	'	-3.8	'
Cost of product/services sold (excluding depreciation, amortization and accretion as shown below):	'	'	'	'
Gathering and processing	0	'	0	'
NGL and crude services	-3.4	'	-3.8	'
Storage and transportation	0	'	'	'
Cost of product/services sold	-3.4	'	-3.8	'
Expenses:	'	'	'	'
Operating and administrative	0	'	0	'
Depreciation, amortization and accretion	0	'	0	'
Other	0	'	0	'
Operating income	0	'	0	'
Other income (expense):	'	'	'	'
Interest and debt expense, net	0	'	0	'
Other	0	'	0	'
Equity in net income of subsidiary	5.1	'	6.2	'
Income (loss) before income taxes	5.1	'	6.2	'
Provision for income taxes	0	'	0	'
Net income (loss)	5.1	'	6.2	'
Net income attributable to non-controlling partners in subsidiary	0	'	0	'
Net income (loss) attributable to Crestwood Equity Partners LP	5.1	'	6.2	'
Consolidated Entities	'	'	'	'
Revenues:	'	'	'	'
Gathering and processing	71.1	'	214.6	'
NGL and crude services	307.3	'	348.8	'
Storage and transportation	48.8	'	55.1	'
Total revenue	427.2	'	618.5	'
Cost of product/services sold (excluding depreciation, amortization and accretion as shown below):	'	'	'	'
Gathering and processing	12.9	'	40.4	'
NGL and crude services	270	'	307.4	'
Storage and transportation	7.1	'	7.7	'
Cost of product/services sold	290	'	355.5	'
Expenses:	'	'	'	'
Operating and administrative	66.3	'	118.2	'
Depreciation, amortization and accretion	55.4	'	105.8	'
Other	-0.3	'	-0.3	'
Operating income	15.8	'	39.3	'
Other income (expense):	'	'	'	'
Interest and debt expense, net	-22.8	'	-46.2	'
Other	-0.4	'	-0.4	'
Equity in net income of subsidiary	0	'	0	'
Income (loss) before income taxes	-7.4	'	-7.3	'
Provision for income taxes	0.5	'	1.2	'
Net income (loss)	-7.9	'	-8.5	'
Net income attributable to non-controlling partners in subsidiary	-0.4	'	6.9	'
Net income (loss) attributable to Crestwood Equity Partners LP	($8.30)	'	($1.60)	'

Condensed_Consolidating_Financ4

Condensed Consolidating Financial Information (Condensed Consolidating Statements of Comprehensive Income) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	($7.90)	$9.10	($8.50)	$21.90
Comprehensive income (loss)	-7.7	9.1	-8.5	21.9
Parent Company	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-7.9	'	-8.5	'
Change in unrealized fair value on cash flow hedges (Note 2)	0.2	'	0	'
Comprehensive income (loss)	-7.7	'	-8.5	'
Guarantor Subsidiaries	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-16.8	'	-19.3	'
Change in unrealized fair value on cash flow hedges (Note 2)	0	'	0	'
Comprehensive income (loss)	-16.8	'	-19.3	'
Non-Guarantor Subsidiaries	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	11.7	'	13.1	'
Change in unrealized fair value on cash flow hedges (Note 2)	0	'	0	'
Comprehensive income (loss)	11.7	'	13.1	'
Consolidation, Eliminations	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	5.1	'	6.2	'
Change in unrealized fair value on cash flow hedges (Note 2)	0	'	0	'
Comprehensive income (loss)	5.1	'	6.2	'
Consolidated Entities	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-7.9	'	-8.5	'
Change in unrealized fair value on cash flow hedges (Note 2)	0.2	'	0	'
Comprehensive income (loss)	($7.70)	'	($8.50)	'

Condensed_Consolidating_Financ5

Condensed Consolidating Financial Information (Condensed Consolidating Statements Of Cash Flows) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Cash flows from operating activities	$114.10	$77.90
Cash flows from investing activities:	'	'
Acquisitions, net of cash acquired	6.1	-469
Purchases of property, plant and equipment	-198.6	-34.3
Investment in unconsolidated affiliates	-152.5	0
Proceeds from sale of assets	11.1	0
Net cash used in investing activities	-333.9	-503.3
Cash flows from financing activities:	'	'
Proceeds from the issuance of long-term debt	216.3	0
Principal payments on long-term debt	-160.2	0
Distributions to members	-43.4	-9.7
Distributions paid to non-controlling partners	-110	-63.9
Net proceeds from the issuance of common units	118.5	217.5
Proceeds from issuance of preferred equity of subsidiary, net	'	0
Net cash provided by financing activities	228.5	424.7
Net increase (decrease) in cash	8.7	-0.7
Cash at beginning of period	0.1	0.8
Cash at end of period	8.8	0.1
Parent Company	'	'
Cash flows from operating activities	0	'
Cash flows from investing activities:	'	'
Acquisitions, net of cash acquired	0.1	'
Purchases of property, plant and equipment	0	'
Investment in unconsolidated affiliates	0	'
Proceeds from sale of assets	0	'
Net cash used in investing activities	0.1	'
Cash flows from financing activities:	'	'
Proceeds from the issuance of long-term debt	0	'
Principal payments on long-term debt	0	'
Distributions to members	0	'
Distributions paid to non-controlling partners	0	'
Net proceeds from the issuance of common units	0	'
Proceeds from issuance of preferred equity of subsidiary, net	0	'
Other	0	'
Net cash provided by financing activities	0	'
Net increase (decrease) in cash	0.1	'
Cash at beginning of period	0	'
Cash at end of period	0.1	'
Guarantor Subsidiaries	'	'
Cash flows from operating activities	-14	'
Cash flows from investing activities:	'	'
Acquisitions, net of cash acquired	5.1	'
Purchases of property, plant and equipment	-9.7	'
Investment in unconsolidated affiliates	0	'
Proceeds from sale of assets	-0.1	'
Net cash used in investing activities	-4.5	'
Cash flows from financing activities:	'	'
Proceeds from the issuance of long-term debt	216.3	'
Principal payments on long-term debt	-160.2	'
Distributions to members	-28.9	'
Distributions paid to non-controlling partners	0	'
Net proceeds from the issuance of common units	0	'
Proceeds from issuance of preferred equity of subsidiary, net	0	'
Other	-6.9	'
Net cash provided by financing activities	20.3	'
Net increase (decrease) in cash	1.8	'
Cash at beginning of period	0	'
Cash at end of period	1.8	'
Non-Guarantor Subsidiaries	'	'
Cash flows from operating activities	128.1	'
Cash flows from investing activities:	'	'
Acquisitions, net of cash acquired	0.9	'
Purchases of property, plant and equipment	-188.9	'
Investment in unconsolidated affiliates	-152.5	'
Proceeds from sale of assets	-11	'
Net cash used in investing activities	-329.5	'
Cash flows from financing activities:	'	'
Proceeds from the issuance of long-term debt	577.2	'
Principal payments on long-term debt	-568.5	'
Distributions to members	-143.5	'
Distributions paid to non-controlling partners	-110	'
Net proceeds from the issuance of common units	356.7	'
Proceeds from issuance of preferred equity of subsidiary, net	96.1	'
Other	0.2	'
Net cash provided by financing activities	208.2	'
Net increase (decrease) in cash	6.8	'
Cash at beginning of period	0.1	'
Cash at end of period	6.9	'
Consolidation, Eliminations	'	'
Cash flows from operating activities	0	'
Cash flows from investing activities:	'	'
Acquisitions, net of cash acquired	0	'
Purchases of property, plant and equipment	0	'
Investment in unconsolidated affiliates	0	'
Proceeds from sale of assets	0	'
Net cash used in investing activities	0	'
Cash flows from financing activities:	'	'
Proceeds from the issuance of long-term debt	0	'
Principal payments on long-term debt	0	'
Distributions to members	0	'
Distributions paid to non-controlling partners	0	'
Net proceeds from the issuance of common units	0	'
Proceeds from issuance of preferred equity of subsidiary, net	0	'
Other	0	'
Net cash provided by financing activities	0	'
Net increase (decrease) in cash	0	'
Cash at beginning of period	0	'
Cash at end of period	0	'
Consolidated Entities	'	'
Cash flows from operating activities	114.1	'
Cash flows from investing activities:	'	'
Acquisitions, net of cash acquired	6.1	'
Purchases of property, plant and equipment	-198.6	'
Investment in unconsolidated affiliates	-152.5	'
Proceeds from sale of assets	-11.1	'
Net cash used in investing activities	-333.9	'
Cash flows from financing activities:	'	'
Proceeds from the issuance of long-term debt	793.5	'
Principal payments on long-term debt	-728.7	'
Distributions to members	-172.4	'
Distributions paid to non-controlling partners	-110	'
Net proceeds from the issuance of common units	356.7	'
Proceeds from issuance of preferred equity of subsidiary, net	96.1	'
Other	-6.7	'
Net cash provided by financing activities	228.5	'
Net increase (decrease) in cash	8.7	'
Cash at beginning of period	0.1	'
Cash at end of period	$8.80	'

Subsequent_Events_Details

Subsequent Events (Details) (USD $)

0 Months Ended

1 Months Ended

0 Months Ended

0 Months Ended

Apr. 05, 2013

Sep. 30, 2013

Dec. 31, 2012

Dec. 07, 2012

Oct. 31, 2013

Oct. 08, 2013

Oct. 30, 2013

Oct. 24, 2013

Oct. 07, 2013

Oct. 24, 2013

Oct. 24, 2013

Sep. 30, 2013

Dec. 31, 2012

Oct. 07, 2013

Oct. 07, 2013

Sep. 30, 2013

Dec. 31, 2012

Oct. 22, 2013

Arrow Midstream Holdings, LLC

Arrow Midstream Holdings, LLC

CMLP

CMLP

CMLP

Cash distribution

Cash distribution

Revolving Loan Facility

Revolving Loan Facility

Revolving Loan Facility

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

CMLP

CMLP

Subsequent Event

CMLP

CMLP

Crestwood Midstream Partners LP and Finance Corp

acre

Subsequent Event

Subsequent Event

Subsequent Event

bbl

mi

ft3

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Declared distribution date

'

'

'

'

'

'

'

'

'

24-Oct-13

24-Oct-13

'

'

'

'

'

'

'

Distribution declared per unit

'

'

'

'

'

'

'

'

'

$0.14

$0.41

'

'

'

'

'

'

'

Distribution payable date

'

'

'

'

'

'

'

'

'

14-Nov-13

'

'

'

'

'

'

'

'

Record Date

'

'

'

'

'

'

'

'

'

7-Nov-13

14-Nov-13

'

'

'

'

'

'

'

Senior Notes, Obligations Assumed in Merger

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$350,000,000

'

'

'

Debt Instrument Assumed in Merger, Interest Rate, Stated Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7.75%

'

'

'

Business Combination, Consideration Transferred

'

'

'

'

'

750,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Payments to Acquire Businesses, Gross

'

'

'

'

550,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Units, Acquisitions

'

'

'

'

8,826,125

'

'

'

'

'

'

'

'

'

'

'

'

'

Gathering pipeline acquired (in miles)

'

'

'

'

'

460

'

'

'

'

'

'

'

'

'

'

'

'

Crude oil gathering pipeline acquired (in miles)

'

'

'

'

'

150

'

'

'

'

'

'

'

'

'

'

'

'

Natural gas gathering pipeline acquired (in miles)

'

'

'

'

'

160

'

'

'

'

'

'

'

'

'

'

'

'

Water gathering pipeline acquired (in miles)

'

'

'

'

'

150

'

'

'

'

'

'

'

'

'

'

'

'

Volume of crude oil for system acquired, per day (in barrels)

'

'

'

'

'

50,000

'

'

'

'

'

'

'

'

'

'

'

'

Volume of natural gas for system acquired, per day (in cubic feet)

'

'

'

'

'

15,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Volume of water for system acquired, per day (in barrels)

'

'

'

'

'

8,500

'

'

'

'

'

'

'

'

'

'

'

'

Central delivery point acquired asset, area (in acres)

'

'

'

'

'

23

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Expiration Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

Credit agreement outstanding carrying value

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000,000

'

'

'

'

Line of Credit Facility, Amount Outstanding

'

'

'

'

'

'

'

'

'

'

'

376,200,000

0

623,600,000

'

'

'

'

Undewriters option for additional units

675,000

'

'

'

'

'

2,100,000

'

773,191

'

'

'

'

'

'

'

'

'

Price per unit, gross

'

'

'

'

'

'

21.19

21.19

21.69

'

'

'

'

'

'

'

'

'

Net proceeds from issuance of Inergy Midstream, L.P. common units

'

'

'

'

'

'

'

296,400,000

16,800,000

'

'

'

'

'

'

'

'

'

Units sold in public offering

'

'

'

'

'

'

'

14,000,000

'

'

'

'

'

'

'

'

'

'

Senior Notes

'

$11,500,000

$0

'

'

'

'

'

'

'

'

'

'

'

'

$351,300,000

$351,500,000

$600,000,000

Debt Instrument, Interest Rate, Stated Percentage

'

7.00%

'

6.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

6.13%

Business Combination, Volume of Crude Oil for System Acquired, Expansion, Per Day

'

'

'

'

'

125,000

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Volume of Natural Gas for System Acquired, Expansion, Per Day

'

'

'

'

'

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Volume of Water for System Acquired, Expansion, Per Day

'

'

'

'

'

40,000

'

'

'

'

'

'

'

'

'

'

'

'