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Document and Entity Information - shares	3 Months Ended
Document and Entity Information - shares	Mar. 31, 2015	May 04, 2015
Document and Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2015
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
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		187,226,238

Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2015	Dec. 31, 2014
Assets
Cash	$ 67.7	$ 8.8
Accounts receivable	289.8	379.6
Inventory	23.9	46.6
Assets from price risk management activities	29.5	79.8
Prepaid expenses and other current assets	27.9	23.3
Total current assets	438.8	538.1
Property, plant and equipment (Note 4)	4,291.7	4,273.9
Less: accumulated depreciation and depletion	414.0	380.1
Property, plant and equipment, net	3,877.7	3,893.8
Intangible assets (Note 4)	1,448.9	1,441.9
Less: accumulated amortization	235.4	210.6
Intangible assets, net	1,213.5	1,231.3
Goodwill	2,491.8	2,491.8
Investment in unconsolidated affiliates (Note 5)	316.6	295.1
Other assets	9.8	11.3
Total assets	8,348.2	8,461.4
Current liabilities:
Accounts payable	218.7	241.2
Accrued expenses and other liabilities (Note 4)	77.8	154.6
Liabilities from price risk management activities	8.6	25.4
Current portion of long-term debt (Note 8)	36.3	3.7
Total current liabilities	341.4	424.9
Long-term debt, less current portion (Note 8)	2,442.8	2,392.8
Other long-term liabilities	48.0	47.2
Deferred income taxes	11.1	12.0
Commitments and contingencies (Note 12)
Partners’ capital (Note 10):
Interest of non-controlling partners in subsidiaries	4,746.9	4,808.3
Total partners’ capital	5,504.9	5,584.5
Total liabilities and partners’ capital	$ 8,348.2	$ 8,461.4

Consolidated Balance Sheets (Parenthetical) - shares	Mar. 31, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Common units, issued	187,249,354	186,403,667
Common units, outstanding	187,249,354	186,403,667

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Revenues:
Gathering and processing	$ 77.3	$ 78.6
Storage and transportation	45.7	51.0
NGL and crude services	607.5	841.1
Related party (Note 13)	1.0	0.9
Total revenue	731.5	971.6
Costs of product/services sold:
Gathering and processing	4.4	7.7
Storage and transportation	3.3	6.8
NGL and crude services	513.7	760.5
Related party (Note 13)	8.3	11.0
Cost of product/services sold	529.7	786.0
Expenses:
Operations and maintenance	50.6	44.1
General and administrative	27.5	27.9
Depreciation, amortization and accretion	74.2	66.3
Total Expenses	152.3	138.3
Gain (loss) on long-lived assets, net	(1.0)	0.5
Loss on contingent consideration	0.0	(2.1)
Operating income	48.5	45.7
Earnings (loss) from unconsolidated affiliates, net	3.4	(0.1)
Interest and debt expense, net	(33.6)	(31.7)
Other income, net	0.2	0.1
Income before income taxes	18.5	14.0
Provision for income taxes	0.4	0.8
Net income	18.1	13.2
Net (income) loss attributable to non-controlling partners	(9.8)	6.4
Net income attributable to Crestwood Equity Partners LP	8.3	19.6
Subordinated unitholders' interest in net income	0.2	0.5
Common unitholders' interest in net income	$ 8.1	$ 19.1
Basic (in dollars per share)	$ 0.04	$ 0.11
Diluted (in dollars per share)	$ 0.04	$ 0.11
Weighted-average limited partners’ units outstanding (in thousands):
Basic (units)	182,801	181,885
Dilutive (units)	4,388	4,388
Diluted (units)	187,189	186,273

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Statement of Comprehensive Income [Abstract]
Net income	$ 18.1	$ 13.2
Change in fair value of Suburban Propane Partners, L.P. units (Note 10)	0.0	(0.8)
Comprehensive income	$ 18.1	$ 12.4

Consolidated Statement of Partners' Capital - 3 months ended Mar. 31, 2015 - USD ($) $ in Millions	Total	Common unit	Non-Controlling Partners	Partners' Capital
Balance at December 31, 2014 at Dec. 31, 2014		$ 776.2	$ 4,808.3	$ 5,584.5
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions to partners		(25.8)	(74.3)	(100.1)
Unit-based compensation charges		0.8	5.0	5.8
Taxes paid for unit-based compensation vesting		(1.4)	(1.7)	(3.1)
Other		(0.1)	(0.2)	(0.3)
Net income	$ 18.1	8.3	9.8	18.1
Balance at March 31, 2015 at Mar. 31, 2015		$ 758.0	$ 4,746.9	$ 5,504.9

Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Operating activities
Net income	$ 18.1	$ 13.2
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	74.2	66.3
Amortization of debt-related deferred costs, discounts and premiums	2.1	1.9
Market adjustment on interest rate swaps	(0.3)	(0.6)
Unit based compensation charges	5.8	5.4
(Gain) loss on long-lived assets, net	1.0	(0.5)
Loss on contingent consideration	0.0	2.1
(Earnings) loss from unconsolidated affiliates, net	(3.4)	0.1
Deferred income taxes	(0.9)	(3.8)
Other	0.4	0.2
Changes in operating assets and liabilities, net of effects from acquisitions	59.6	(2.4)
Net cash provided by operating activities	156.6	81.9
Investing activities
Acquisitions, net of cash acquired (Note 3)	0.0	(12.1)
Purchases of property, plant and equipment	(47.4)	(82.4)
Investment in unconsolidated affiliates	(18.1)	(19.8)
Proceeds from sale of assets	0.5	0.0
Other	(0.2)	0.0
Net cash used in investing activities	(65.2)	(114.3)
Financing activities
Proceeds from the issuance of long-term debt	1,252.7	496.4
Principal payments on long-term debt	(1,169.9)	(372.6)
Payments on capital leases	(0.7)	(1.1)
Payments for debt-related deferred costs	(11.1)	0.0
Distributions to partners	(25.8)	(25.6)
Distributions paid to non-controlling partners	(74.3)	(74.1)
Net proceeds from issuance of preferred equity of subsidiary	0.0	12.3
Taxes paid for unit-based compensation vesting	3.1	0.4
Other	(0.3)	0.0
Net cash provided by (used in) financing activities	(32.5)	34.9
Net change in cash	58.9	2.5
Cash at beginning of period	8.8	5.2
Cash at end of period	67.7	7.7
Supplemental schedule of noncash investing and financing activities
Net change to property, plant and equipment through accounts payable and accrued expenses	$ (9.1)	$ (3.4)

Business Description

3 Months Ended

Mar. 31, 2015

Disclosure Partnership Organization And Basis Of Presentation Narrative [Abstract]

Business Description

Crestwood Equity Partners LP (the Company or Crestwood) is a publicly-traded (NYSE: CEQP) Delaware limited partnership that provides midstream solutions to customers in the crude oil, natural gas liquids (NGLs) and natural gas sectors of the energy industry. We are engaged primarily in the gathering, processing, storage and transportation of natural gas and NGLs, the marketing of NGLs, and the gathering, storage and transportation of crude oil.

Our general partner, Crestwood Equity GP LLC, owns our non-economic general partnership interest. Our general partner is indirectly owned by Crestwood Holdings LLC (Crestwood Holdings), which is substantially owned and controlled by First Reserve Management, L.P. (First Reserve). As of March 31, 2015, Crestwood Holdings also owns approximately 11% of the Crestwood Midstream Partners LP (Crestwood Midstream or CMLP) common units. As of March 31, 2015, First Reserve owns approximately 26% of our common units, and 4,387,889 of our subordinated units.

We indirectly own Crestwood Midstream GP LLC, the non-economic general partner of Crestwood Midstream and, consequently, manage and control Crestwood Midstream. As of March 31, 2015, we also own approximately 4% of Crestwood Midstream’s limited partnership interests and 100% of its incentive distribution rights (IDRs), which entitle us to receive 50% of all distributions paid by Crestwood Midstream in excess of its initial quarterly distribution of $0.37 per common unit.

Our financial statements reflect three operating and reporting segments, including:

•

Gathering and Processing: our gathering and processing (G&P) operations provide natural gas gathering, processing, treating, compression, transportation services and sales of natural gas and the delivery of NGLs to producers in unconventional shale plays and tight-gas plays in West Virginia, Wyoming, Texas, Arkansas, New Mexico and Louisiana. This segment primarily includes our rich gas gathering systems and processing plants in the Marcellus, Powder River Basin (PRB) Niobrara, Barnett, and Permian Shale plays, and our dry gas gathering systems in the Barnett, Fayetteville, and Haynesville Shale plays;

•

Storage and Transportation: our storage and transportation operations provide regulated natural gas storage and transportation services to producers, utilities and other customers. This segment primarily includes our natural gas storage facilities (Stagecoach, Thomas Corners, Steuben and Seneca Lake), and our natural gas transmission facilities (the North-South Facilities, the MARC I Pipeline and the East Pipeline) in New York and Pennsylvania; and

•

NGL and Crude Services: our NGL and crude services operations provide NGL and crude oil gathering, storage, marketing and transportation services to producers, refiners, marketers and other customers. This segment primarily includes our NGL marketing, supply and logistics business (including our West Coast processing and fractionation operations, Seymour NGL storage facility, and our rail-to-truck terminals and a fleet of transportation assets) and our integrated Bakken crude oil footprint in North Dakota, which consists of (i) the COLT Hub, a crude oil rail loading and storage terminal, (ii) the Arrow crude oil, natural gas and water gathering systems, and (iii) our fleet of over-the-road crude and produced water transportation assets. This segment also includes our solution-mining and salt production company (US Salt), and Bath storage facility in New York.

We own and operate a proprietary NGL supply and logistics business (including our West Coast processing and fractionation facility, Seymour storage facility, terminals and transportation fleet). All of our other consolidated assets are owned by or through Crestwood Midstream.

On May 5, 2015, CEQP, CMLP and certain of its affiliates entered into a definitive agreement under which CMLP has agreed to merge with a wholly-owned subsidiary of CEQP, with CMLP surviving as a wholly-owned subsidiary of CEQP. As part of the merger consideration, CMLP’s unitholders will become unitholders of CEQP in a tax free exchange, with CMLP’s common unitholders receiving 2.75 common units of CEQP for each common unit of CMLP held upon completion of the merger. CMLP’s IDRs will also be eliminated upon completion of the merger and CMLP’s common units will cease to be listed on the NYSE. CMLP expects to complete the merger in the third quarter of 2015, subject to the approval of Crestwood Midstream's unitholders and customary closing conditions.

Unless otherwise indicated, references in this report to “we,” “us,” “our,” “ours,” “our company,” the “partnership,” the “Company,” “CEQP,” “Crestwood,” and similar terms refer to either Crestwood Equity Partners LP itself or Crestwood Equity Partners LP and its consolidated subsidiaries, as the context requires.

Summary of Significant Accounting Policies	3 Months Ended
Summary of Significant Accounting Policies	Mar. 31, 2015
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Basis of Presentation and Summary of Significant Accounting Policies Basis of Presentation The financial information as of March 31, 2015, and for the three months ended March 31, 2015 and 2014, is unaudited. The consolidated balance sheet as of December 31, 2014, was derived from the audited balance sheet filed in our 2014 Annual Report on Form 10-K. Our consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) and include the accounts of all consolidated subsidiaries after the elimination of all intercompany accounts and transactions. In management’s opinion, all necessary adjustments to fairly present our results of operations, financial position and cash flows for the periods presented have been made and all such adjustments are of a normal and recurring nature. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). Our consolidated financial statements for the prior period include reclassifications that were made to conform to the current period presentation. Cash inflows of $9.6 million related to reimbursements of capital expenditures from producers have been reclassified from investing activities to changes in operating assets and liabilities, net of effects from acquisitions under operating activities in our consolidated statements of cash flows for the three months ended March 31, 2014 to conform with the current period presentation. The reclassification was not significant to our previously reported consolidated financial statements. The accompanying consolidated financial statements should be read in conjunction with our 2014 Annual Report on Form 10-K filed with the SEC on February 27, 2015. Significant Accounting Policies There were no material changes in our significant accounting policies from those described in our 2014 Annual Report on Form 10-K. New Accounting Pronouncements Issued But Not Yet Adopted As of March 31, 2015, the following accounting standards had not yet been adopted by us. In May 2014, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update 2014-09, Revenue from Contracts with Customers, which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes current revenue recognition guidance. We expect to adopt the provisions of this standard effective January 1, 2017 and are currently evaluating the impact that this standard will have on our consolidated financial statements. In April 2015, the FASB proposed deferring the effective date of this standard by one year. In February 2015, the FASB issued Accounting Standards Update 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis, which provides additional guidance on the consolidation of limited partnerships and on the evaluation of variable interest entities. We expect to adopt the provisions of this standard effective January 1, 2016 and are currently evaluating the impact, if any, that this standard may have on our consolidated financial statements. In April 2015, the FASB issued Accounting Standards Update 2015-03, Interest - Imputation of Interest (Subtopic 835-30), which requires deferred debt issuance costs to be classified as a reduction of the debt liability rather than as an asset in the balance sheet. We expect to adopt the provisions of this standard effective January 1, 2016, and do not currently anticipate it will have a significant impact on our consolidated financial statements.

Acquisitions	3 Months Ended
Acquisitions	Mar. 31, 2015
Business Combinations [Abstract]
Acquisitions	Acquisitions 2014 Acquisitions Crude Transportation Acquisition (Bakken) Red Rock. On March 21, 2014, Crestwood Midstream purchased substantially all of the trucking operations of Red Rock Transportation Inc. (Red Rock) for approximately $13.8 million, comprised of $12.1 million paid at closing plus deferred payments of $1.8 million. These operations are located in Watford City, North Dakota and provide crude oil and produced water hauling services to the oilfields of western North Dakota and eastern Montana. The acquired assets include a fleet of approximately 56 trailer tanks, 22 double bottom body tanks and 44 tractors with 28,000 barrels per day of transportation capacity. In the first quarter of 2014, we finalized the purchase price and allocated approximately $10.6 million of the purchase price to property, plant and equipment and intangible assets and approximately $3.2 million to goodwill. Goodwill recognized relates primarily to anticipated operating synergies between the assets acquired and our existing assets. These assets are included in our NGL and crude services segment. This acquisition was not material to our NGL and crude services segment's results of operations for the three months ended March 31, 2014. In addition, transaction costs related to this acquisition was not material for the three months ended March 31, 2014.

- Definition

The entire disclosure for a business combination (or series of individually immaterial business combinations) completed during the period, including background, timing, and recognized assets and liabilities. The disclosure may include leverage buyout transactions (as applicable).

+ References

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+ Details

Certain Balance Sheet Information

3 Months Ended

Mar. 31, 2015

Balance Sheet Related Disclosures [Abstract]

Certain Balance Sheet Information

Property, Plant and Equipment

Property, plant and equipment consisted of the following at March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015		December 31, 2014
Gathering systems and pipelines	$	1,417.8	$	1,410.9
Facilities and equipment	1,638.0		1,648.3
Buildings, land, rights-of-way, storage contracts and easements	843.5		841.5
Vehicles	46.6		45.2
Construction in process	174.1		156.5
Base gas	37.5		37.5
Salt deposits	120.5		120.5
Office furniture and fixtures	13.7		13.5
	4,291.7		4,273.9
Less: accumulated depreciation and depletion	414.0		380.1
Total property, plant and equipment, net	$	3,877.7	$	3,893.8

Capital Leases. We have a treating facility and certain auto leases which are accounted for as capital leases. Our treating facility lease is reflected in facilities and equipment in the above table. We had capital lease assets of $5.5 million and $5.3 million included in property, plant and equipment, net at March 31, 2015 and December 31, 2014.

Intangible Assets

Intangible assets consisted of the following at March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015		December 31, 2014
Customer accounts	$	583.7	$	583.7
Covenants not to compete	9.6		9.6
Gas gathering, compression and processing contracts	726.1		730.2
Acquired storage contracts	29.0		29.0
Trademarks	32.2		32.2
Deferred financing costs	68.3		57.2
	1,448.9		1,441.9
Less: accumulated amortization	235.4		210.6
Total intangible assets, net	$	1,213.5	$	1,231.3

Accrued Expenses and Other Liabilities

Accrued expenses and other liabilities consisted of the following at March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015		December 31, 2014
Accrued expenses	$	36.3	$	52.5
Accrued property taxes	4.5		2.2
Accrued product purchases payable	0.4		0.7
Tax payable	—		1.6
Interest payable	14.5		23.5
Accrued additions to property, plant and equipment	9.1		20.0
Commitments and contingent liabilities (Note 12)	—		40.0
Capital leases	1.7		1.9
Deferred revenue	11.3		12.2
Total accrued expenses and other liabilities	$	77.8	$	154.6

Investments in Unconsolidated Affiliates

3 Months Ended

Mar. 31, 2015

Equity Method Investments and Joint Ventures [Abstract]

Investments in Unconsolidated Affiliates

Net Investment and Earnings (Loss)

Our net investments in and earnings (loss) from our unconsolidated affiliates are as follows (in millions, unless otherwise stated):



	Ownership Percentage			Investment				Earnings (Loss) from Unconsolidated Affiliates
	March 31,			March 31,		December 31,		Three Months Ended March 31,
	2015			2015		2014		2015		2014
Jackalope Gas Gathering Services, L.L.C.⁽¹⁾	50.00	%	⁽⁴⁾	$	244.2	$	232.9	$	2.5	$	0.3
Tres Palacios Holdings LLC⁽²⁾	50.01	%		42.8		36.0		0.9		—
Powder River Basin Industrial Complex, LLC⁽³⁾	50.01	%		29.6		26.2		—		(0.4		)
Total				$	316.6	$	295.1	$	3.4	$	(0.1	)

(1)

As of March 31, 2015, our investment balance exceeded our equity in the underlying net assets of Jackalope Gas Gathering Services, L.L.C. (Jackalope) by approximately $52.9 million. We amortize and generally assess the recoverability of this amount over 20 years, which represents the life of Jackalope’s gathering agreement with Chesapeake Energy Corporation and RKI Exploration and Production, LLC, and reflect the amortization as a reduction of our earnings from unconsolidated affiliates. For the three months ended March 31, 2015 and 2014, we recorded amortization of approximately $0.8 million. Our Jackalope investment is included in our gathering and processing segment.

(2)

In December 2014, one of our consolidated subsidiaries and an affiliate of Brookfield Infrastructure Group (Brookfield) formed the Tres Palacios Holdings LLC (Tres Holdings) joint venture. For more information on our joint venture, see our 2014 Annual Report on Form 10-K filed with the SEC. As of March 31, 2015, our equity in the underlying net assets exceeded our investment balance in Tres Holdings by approximately $30.0 million. We amortize and generally assess the recoverability of this amount over the life of the Tres Palacios Gas Storage LLC (Tres Palacios) sublease agreement, and reflect the amortization as an increase of our earnings from unconsolidated affiliates. For the three months ended March 31, 2015, we recorded amortization of approximately $0.3 million. Our Tres Holdings investment is included in our storage and transportation segment.


(3)	As of March 31, 2015, our investment balance approximated our equity in the underlying net assets of Powder River Basin Industrial Complex, LLC (PRBIC). Our PRBIC investment is included in our NGL and crude services segment.


(4)	Excludes non-controlling interests related to our investment in Jackalope. See Note 10 for a further discussion of our non-controlling interest related to our investment in Jackalope.

Distributions and Contributions

Jackalope. Jackalope is required, within 30 days following the end of each quarter, to make quarterly distributions of its available cash to its members based on their respective ownership percentage. During the three months ended March 31, 2015 and 2014, Jackalope did not make any distributions to its members. In April 2015, we received a cash distribution of approximately $4.5 million from Jackalope. During the three months ended March 31, 2015 and 2014, we contributed approximately $8.8 million and $17.3 million to Jackalope.

Tres Holdings. Tres Holdings is required, within 30 days following the end of each quarter, to make quarterly distributions of its available cash (as defined in its limited liability company agreement) to its members based on their respective ownership percentage. In April 2015, we received a cash distribution of approximately $2.1 million from Tres Holdings. During the three months ended March 31, 2015, we contributed approximately $5.9 million in Tres Holdings.

PRBIC. PRBIC is required to make quarterly distributions of its available cash to its members based on their respective ownership percentage. During the three months ended March 31, 2015, we received a cash distribution of approximately $0.3 million from PRBIC as a return of capital. During the three months ended March 31, 2014, PRBIC did not make any distributions to its members. In addition, during the three months ended March 31, 2015 and 2014, we contributed approximately $3.7 million and $2.5 million to PRBIC.

Risk Management

3 Months Ended

Mar. 31, 2015

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

Risk Management

We are exposed to certain market risks related to our ongoing business operations. These risks include exposure to changing commodity prices as well as fluctuations in interest rates. We utilize derivative instruments to manage our exposure to fluctuations in commodity prices, which is discussed below. We also periodically utilize derivative instruments to manage our exposure to fluctuations in interest rates, which is discussed in Note 8. Additional information related to our derivatives is discussed in Note 7.

Commodity Derivative Instruments and Price Risk Management

Risk Management Activities

We sell NGLs to energy related businesses and may use a variety of financial and other instruments including forward contracts involving physical delivery of NGLs, heating oil and crude oil. We will periodically enter into offsetting positions to economically hedge against the exposure our customer contracts create. Certain of these contracts and positions are derivative instruments. We do not designate any of our commodity-based derivatives as hedging instruments for accounting purposes. Our commodity-based derivatives are reflected at fair value in the consolidated balance sheets, and changes in the fair value of these derivatives that impact the consolidated statements of operations are reflected in costs of product/services sold. During the three months ended March 31, 2015 and 2014, the impact to the statement of operations related to our commodity-based derivatives reflected in costs of product/services sold was a loss of $2.9 million and $0.5 million. We attempt to balance our contractual portfolio in terms of notional amounts and timing of performance and delivery obligations. This balance in the contractual portfolio significantly reduces the volatility in costs of product/services sold related to these instruments.

Commodity Price and Credit Risk

Notional Amounts and Terms

The notional amounts and terms of our derivative financial instruments include the following at March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015		December 31, 2014
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, crude and heating oil (barrels)	5.9	6.8	6.8	8.4
Natural gas (MMBTU’s)	—	—	0.2	0.1

Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly, notional amounts do not reflect our monetary exposure to market or credit risks.

All contracts subject to price risk had a maturity of 36 months or less; however, 94% of the contracts expire within 12 months.

Credit Risk

Inherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. The counterparties associated with assets from price risk management activities as of March 31, 2015 and December 31, 2014 were energy marketers and propane retailers, resellers and dealers.

Certain of our derivative instruments have credit limits that require us to post collateral. The amount of collateral required to be posted is a function of the net liability position of the derivative as well as our established credit limit with the respective counterparty. If our credit rating were to change, the counterparties could require us to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent of change in our credit rating as well as the requirements of the individual counterparty. The aggregate fair value of all commodity derivative instruments with credit-risk-related contingent features that were in a liability position at March 31, 2015 was $6.3 million, for which we posted no collateral and at December 31, 2014 was $5.2 million for which we posted $1.8 million of collateral in the normal course of business. In addition, at March 31, 2015 and December 31, 2014, we had a New York Mercantile Exchange (NYMEX) related net derivative liability position of $21.3 million and $36.9 million, for which we posted $28.9 million and $41.9 million of cash collateral in the normal course of business. At March 31, 2015 and December 31, 2014, we also received collateral of $11.8 million and $33.6 million in the normal course of business. All collateral amounts have been netted against the asset or liability with the respective counterparty and is reflected in our consolidated balance sheets as assets and liabilities from price risk management activities.

- Definition

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

+ References

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+ Details

Fair Value Measurements

3 Months Ended

Mar. 31, 2015

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

Fair Value Measurements

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

•

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

•

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


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

Cash and Cash Equivalents, Accounts Receivable and Accounts Payable

As of March 31, 2015 and December 31, 2014, the carrying amounts of cash, accounts receivable and accounts payable represent fair value based on the short-term nature of these instruments.

Credit Facilities

The fair value of the amounts outstanding under our credit facilities approximates their carrying amounts as of March 31, 2015 and December 31, 2014 due primarily to the variable nature of the interest rates of the instruments, which is considered a Level 2 fair value measurement.

Senior Notes

We estimate the fair value of our senior notes primarily based on quoted market prices for the same or similar issuances (representing a Level 2 fair value measurement). The following table reflects the carrying value and fair value of our senior notes (in millions):



	March 31, 2015				December 31, 2014
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
CEQP Senior Notes	$	10.6	$	10.6	$	11.4	$	11.6
Crestwood Midstream 2019 Senior Notes	$	350.9	$	363.6	$	351.0	$	360.5
Crestwood Midstream 2020 Senior Notes	$	503.8	$	500.3	$	504.0	$	481.6
Crestwood Midstream 2022 Senior Notes	$	600.0	$	607.5	$	600.0	$	568.5
Crestwood Midstream 2023 Senior Notes	$	700.0	$	710.5	$	—	$	—

Financial Assets and Liabilities

As of March 31, 2015 and December 31, 2014, we held certain assets and liabilities that are required to be measured at fair value on a recurring basis, which include our derivative instruments related to heating oil, crude oil, NGLs and interest rates. Our derivative instruments consist of forwards, swaps, futures, physical exchanges and options.

Certain of our derivative instruments are traded on the NYMEX. These instruments have been categorized as Level 1.

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

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

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

The following tables set forth by level within the fair value hierarchy, our assets and liabilities that were accounted for at fair value on a recurring basis at March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Total		Netting Agreements⁽¹⁾			Total
Assets
Assets from price risk management	$	—	$	41.1	$	—	$	41.1	$	(11.6	)	$	29.5
Suburban Propane Partners, L.P. units⁽²⁾	6.1		—		—		6.1		—			6.1
Total assets at fair value	$	6.1	$	41.1	$	—	$	47.2	$	(11.6	)	$	35.6

Liabilities
Liabilities from price risk management	$	0.2	$	35.2	$	—	$	35.4	$	(26.8	)	$	8.6
Interest rate swaps⁽³⁾	—		1.3		—		1.3		—			1.3
Total liabilities at fair value	$	0.2	$	36.5	$	—	$	36.7	$	(26.8	)	$	9.9



	December 31, 2014
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Total		Netting Agreements⁽¹⁾			Total
Assets
Assets from price risk management	$	0.5	$	146.7	$	—	$	147.2	$	(67.4	)	$	79.8
Suburban Propane Partners, L.P. units⁽²⁾	6.1		—		—		6.1		—			6.1
Total assets at fair value	$	6.6	$	146.7	$	—	$	153.3	$	(67.4	)	$	85.9

Liabilities
Liabilities from price risk management	$	1.6	$	99.2	$	—	$	100.8	$	(75.4	)	$	25.4
Interest rate swaps⁽³⁾	—		1.6		—		1.6		—			1.6
Total liabilities at fair value	$	1.6	$	100.8	$	—	$	102.4	$	(75.4	)	$	27.0


(1)	Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions as well as cash collateral held or placed with the same counterparties.


(2)	Our Suburban Propane Partners, L.P. units are included in prepaid expenses and other current assets on our consolidated balance sheets.


(3)	Interest rate swaps are included in other long-term liabilities on our consolidated balance sheets.

Long-Term Debt

3 Months Ended

Mar. 31, 2015

Text Block [Abstract]

Long-Term Debt

Long-term debt consisted of the following at March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015		December 31, 2014
CEQP Credit Facility	$	308.0	$	369.0
CEQP Senior Notes	10.6		11.4
Crestwood Midstream Revolver	—		555.0
Crestwood Midstream 2019 Senior Notes	350.0		350.0
Premium on Crestwood Midstream 2019 Senior Notes	0.9		1.0
Crestwood Midstream 2020 Senior Notes	500.0		500.0
Fair value adjustment of Crestwood Midstream 2020 Senior Notes	3.8		4.0
Crestwood Midstream 2022 Senior Notes	600.0		600.0
Crestwood Midstream 2023 Senior Notes	700.0		—
Other	5.8		6.1
Total debt	2,479.1		2,396.5
Less: current portion	36.3		3.7
Total long-term debt	$	2,442.8	$	2,392.8

We and our subsidiaries do not provide credit support or guarantee any amounts outstanding under the credit facility or notes of Crestwood Midstream. Crestwood Midstream and its subsidiaries do not provide credit support or guarantee any amounts outstanding under our credit facility or senior notes.

CEQP Credit Facility

Description of Credit Facility. We utilize a secured credit facility (the CEQP Credit Facility) with an aggregate revolving loan capacity of $495 million, to fund working capital requirements, capital expenditures and acquisitions and for general partnership purposes. All borrowings under the CEQP Credit Facility, which expires in July 2016, are generally secured by substantially all of our assets and the equity interests in all of our wholly owned subsidiaries.

At March 31, 2015, we had $134.3 million of available capacity under the revolving credit facility (excluding standby letters of credit) considering our most restrictive debt covenants under the facility. At March 31, 2015 and December 31, 2014, our outstanding standby letters of credit were $52.7 million and $56.7 million. The interest rates on the CEQP Credit Facility are based on the prime rate and LIBOR plus the applicable spreads, resulting in interest rates which were between 2.43% and 4.50% at March 31, 2015. The weighted-average interest rate as of March 31, 2015 and December 31, 2014 was 2.43% and 3.02%.

Restrictive Covenants. The CEQP Credit Facility contains the following financial covenants:


•	the ratio of our total funded debt (as defined in the credit agreement) to consolidated EBITDA (as defined in the credit agreement) was amended in September 2014 to increase the ratio to (i) 5.25 to 1.0 for the quarter ended March 31, 2015, (ii) 5.00 to 1.0 for the quarter ended June 30, 2015, and (iii) 4.75 to 1.0 for the quarter ended September 30, 2015 and all subsequent quarters.


•	the ratio of our consolidated EBITDA to consolidated interest expense (as defined in the credit agreement), for the four quarters then most recently ended, must not be less than 2.50 to 1.0.

At March 31, 2015, the total funded debt to consolidated EBITDA was approximately 3.25 to 1.0 and consolidated EBITDA to consolidated interest expense was approximately 7.91 to 1.0.

At March 31, 2015, we were in compliance with the debt covenants in the CEQP Credit Facility. For additional information regarding our debt covenants, see our 2014 Annual Report on Form 10-K as filed with the SEC.

Interest Rate Swaps. We enter into interest rate swaps to reduce our exposure to variable interest payments due under the CEQP Credit Facility. These swap agreements require us to make quarterly payments to the counterparty on an aggregate notional amount based on fixed rates. In exchange, the counterparty is required to make quarterly floating interest rate payments on the same date to us based on the three-month LIBOR applied to the same aggregate notional amount. In February 2015, five of our interest rate swaps matured, with an aggregate notional amount of $175.0 million and fixed rates ranging from 0.84% to 2.35%. As of March 31, 2015, we had one swap agreement, with a notional amount of $50 million and a fixed rate of 2.52%. This agreement matures in 2016. During the three months ended March 31, 2015, we recorded a gain of approximately $0.3 million associated with these interest rate swaps, which is reflected as a reduction of our interest and debt expense, net on our consolidated statements of operations.

CEQP Senior Notes

At March 31, 2015, we had $10.6 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.

Crestwood Midstream Revolver

Description of Facility. Crestwood Midstream has a five-year $1.0 billion senior secured revolving credit facility (the Crestwood Midstream Revolver), which expires in October 2018 and is available to fund acquisitions, working capital and internal growth projects and for general partnership purposes. The Crestwood Midstream Revolver includes a sub-limit up to $25 million for same-day swing line advances and a sub-limit up to $250 million for letters of credit. Subject to limited exception, the Crestwood Midstream Revolver is secured by substantially all of the equity interests and assets of Crestwood Midstream’s subsidiaries, except for Crestwood Niobrara LLC (Crestwood Niobrara), PRBIC and Tres Holdings and their respective subsidiaries.

At March 31, 2015, Crestwood Midstream had $429.1 million of available capacity under the Crestwood Midstream Revolver considering the most restrictive debt covenants in its credit agreement. In March 2015, Crestwood Midstream utilized proceeds from its 2023 Senior Notes offerings to pay the outstanding balance on its Credit Facility as discussed below. At March 31, 2015 and December 31, 2014, its outstanding standby letters of credit were $5.6 million and $15.1 million. Borrowings under the Crestwood Midstream Revolver accrue interest at prime or LIBOR-based rates plus applicable spreads, which resulted in interest rates between 2.66% and 4.75% at December 31, 2014. The weighted-average interest rate as of December 31, 2014 was 2.86%.

Restrictive Covenants. Crestwood Midstream is required under its credit agreement to maintain a net debt to consolidated EBITDA ratio (as defined in its credit agreement) of not more than 5.00 to 1.0 (or, if applicable, 5.50 to 1.0 during certain periods immediately following a material acquisition by Crestwood Midstream) and a consolidated EBITDA to consolidated interest expense ratio (as defined in its credit agreement) of not less than 2.50 to 1.0. As a result of Crestwood Midstream's election to increase the permitted net debt to consolidated EBITDA ratio in conjunction with its 50.01% acquisition of Tres Palacios Gas Storage Company LLC, the net debt to consolidated EBITDA ratio required by its credit agreement is 5.50 for a 270-day period commencing December 3, 2014. At March 31, 2015, the net debt to consolidated EBITDA was approximately 4.58 to 1.0 and consolidated EBITDA to consolidated interest expense was approximately 4.15 to 1.0.

Crestwood Midstream Senior Notes

As of March 31, 2015, Crestwood Midstream had four series of senior unsecured notes outstanding, including (i) $350 million in aggregate principal amount of 7.75% Senior Notes due 2019 (the 2019 Senior Notes), (ii) $500 million in aggregate principal amount of 6.0% Senior Notes due 2020 (the 2020 Senior Notes), (iii) $600 million in aggregate principal amount of 6.125% Senior Notes due 2022 (the 2022 Senior Notes), and (iv) $700 million in aggregate principal amount of 6.25% Senior Notes due 2023 (the 2023 Senior Notes and together with the 2019 Senior Notes, 2020 Senior Notes and 2022 Senior Notes, its Senior Notes). Crestwood Midstream's Senior Notes are guaranteed on a senior unsecured basis by all of its domestic restricted subsidiaries, subject to certain exceptions.

In March 2015, Crestwood Midstream issued $700 million of 6.25% unsecured Senior Notes due 2023 in a private offering. The 2023 Senior Notes will mature on April 1, 2023, and interest is payable semiannually in arrears on April 1 and October 1 of each year, beginning October 1, 2015. The net proceeds from this offering of approximately $688.9 million were used to pay down borrowings under the Crestwood Midstream Revolver and for Crestwood Midstream’s general partnership purposes.

On April 8, 2015, Crestwood Midstream redeemed its 2019 Senior Notes for approximately $364.1 million, including accrued interest of $0.5 million and a call premium of $13.6 million. Crestwood Midstream utilized approximately $315 million of its credit facility to redeem all of its outstanding 2019 Senior Notes.

At March 31, 2015, Crestwood Midstream was in compliance with all of its debt covenants applicable to the Crestwood Midstream Revolver and its Senior Notes. For additional information regarding the Crestwood Midstream debt covenants, see our 2014 Annual Report on Form 10-K filed with the SEC.

Other

For a description of our non-interest bearing obligations due under noncompetition agreements and other note payable agreements, see our 2014 Annual Report on Form 10-K filed with the SEC.

Earnings Per Limited Partner Unit	3 Months Ended
Earnings Per Limited Partner Unit	Mar. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Limited Partner Unit	Earnings Per Limited Partner Unit Our net income (loss) attributable to Crestwood Equity Partners is allocated to the subordinated and limited partner unitholders based on their ownership percentage. We calculate basic net income per limited partner unit using 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 outstanding. There were no units excluded from our dilutive earnings per share as we did not have any anti-dilutive units for the three months ended March 31, 2015 and 2014.

Partners' Capital

3 Months Ended

Mar. 31, 2015

Statement of Partners' Capital [Abstract]

Partners' Capital

Partners’ Capital

Distributions

Distributions to Partners

A summary of our limited partner quarterly cash distributions for the three months ended March 31, 2015 and 2014 is presented below:



Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2015
February 6, 2015	February 13, 2015	$	0.1375	$	25.8
2014
February 7, 2014	February 14, 2014	$	0.1375	$	25.6

On April 23, 2015, we declared a distribution of $0.1375 per limited partner unit to be paid on May 15, 2015, to unitholders of record on May 8, 2015 with respect to the first quarter of 2015.

Non-Controlling Partners

Crestwood Midstream Class A Preferred Units

On June 17, 2014, Crestwood Midstream entered into definitive agreements with a group of investors, including Magnetar Financial, affiliates of GSO Capital Partners LP and GE Energy Financial Services (the Class A Purchasers). Under these agreements, Crestwood Midstream has agreed to sell to the Class A Purchasers and the Class A Purchasers have agreed to purchase from Crestwood Midstream up to $500 million of Preferred Units at a fixed price of $25.10 per unit on or before September 30, 2015. During the three months ended March 31, 2015 and through the date of this filing, we did not sell any Preferred Units to the Class A Purchasers under these agreements. For additional information on Crestwood Midstream's Class A Preferred Units, see our 2014 Annual Report on Form 10-K filed with the SEC.

Crestwood Niobrara Preferred Interest

Crestwood Niobrara issued a preferred interest to a subsidiary of General Electric Capital Corporation and GE Structured Finance, Inc. (collectively, GE) in conjunction with the acquisition of its investment in Jackalope, which is reflected as non-controlling interest in our consolidated financial statements. During the three months ended March 31, 2014, GE made capital contributions of $12.3 million to Crestwood Niobrara in exchange for an equivalent number of preferred units.

Net Income (Loss) Attributable to Non-Controlling Partners

The components of net income (loss) attributable to non-controlling partners on our consolidated statements of operations for the three months ended March 31, 2015 and 2014, are as follows (in millions):



	Three Months Ended
	March 31,
	2015			2014
Crestwood Midstream limited partner interests	$	(5.0	)	$	(9.5	)
Crestwood Midstream Class A preferred units	9.2			—
Crestwood Niobrara preferred interests	5.6			3.1
Net income (loss) attributable to non-controlling partners	$	9.8		$	(6.4	)

Distributions to Non-Controlling Partners

Crestwood Midstream Limited Partners. The Crestwood Midstream partnership agreement requires them to distribute, within 45 days after the end of each quarter, all available cash (as defined in its partnership agreement) to unitholders of record on the applicable record date. We are not entitled to distributions on our non-economic general partner interest in Crestwood Midstream. Crestwood Midstream paid cash distributions to its limited partners (excluding distributions to its general partner and distributions on the limited partner units owned by us) of $74.3 million and $74.1 million during the three months ended March 31, 2015 and 2014.

Crestwood Midstream Class A Preferred Unitholders. Crestwood Midstream's partnership agreement requires it to make quarterly distributions to its Class A Preferred Unit holders. The holders of the Class A Preferred Units (the Preferred Units) are entitled to receive fixed quarterly distributions of $0.5804 per unit. For the 12 quarters following the quarter ended June 30, 2014 (the Initial Distribution Period), distributions on the Preferred Units can be made in additional Preferred Units, cash, or a combination thereof, at Crestwood Midstream's election. If Crestwood Midstream elects to pay the quarterly distribution through the issuance of additional Preferred Units, the number of units to be distributed will be calculated as the fixed quarterly distribution of $0.5804 per unit divided by the cash purchase price of $25.10 per unit. Crestwood Midstream accrues the fair value of such distribution at the end of the quarterly period and adjusts the fair value of the distribution on the date the additional Preferred Units are distributed. Distributions on the Preferred Units following the Initial Distribution Period will be made in cash unless, subject to certain exceptions, (i) there is no distribution being paid on Crestwood Midstream's common units and (ii) its available cash (as defined in its partnership agreement) is insufficient to make a cash distribution to its Preferred Unit holders. If Crestwood Midstream fails to pay the full amount payable to its Preferred Unit holders in cash following the Initial Distribution Period, then (x) the fixed quarterly distribution on the Preferred Units will increase to $0.7059 per unit, and (y) Crestwood Midstream will not be permitted to declare or make any distributions to its common unitholders until such time as all accrued and unpaid distributions on the Preferred Units have been paid in full in cash. In addition, if Crestwood Midstream fails to pay in full any Class A Preferred Distribution (as defined in its partnership agreement), the amount of such unpaid distribution will accrue and accumulate from the last day of the quarter for which such distribution is due until paid in full, and any accrued and unpaid distributions will be increased at a rate of 2.8125% per quarter.

On April 23, 2015, the board of directors of our general partner authorized the issuance of 423,903 Class A Preferred Units to our preferred unitholders for the quarter ended March 31, 2015 in lieu of paying a cash distribution. On February 13, 2015, Crestwood Midstream issued 414,325 Class A Preferred Units to its preferred unitholders for the quarter ended December 31, 2014 in lieu of paying a cash distribution.

Crestwood Niobrara Preferred Unitholders. During the three months ended March 31, 2015 and 2014, Crestwood Niobrara issued 3,680,570 and 2,210,294 preferred units to GE in lieu of paying a cash distribution. Beginning in the first quarter of 2015, Crestwood Niobrara no longer had the option to pay distributions to GE by issuing additional preferred units in lieu of paying a cash distribution. On April 30, 2015, Crestwood Niobrara paid a distribution of $3.8 million to GE for the quarter ended March 31, 2015.

Other Partners’ Capital Transactions

Equity Distribution Agreement

Crestwood Midstream entered into an equity distribution program with certain financial institutions (each, a Manager) under which it is allowed to offer and sell, from time to time through one or more of the Managers, common units having an aggregate offering price of up to $300.0 million. Crestwood Midstream will pay the Managers an aggregate fee of up to 2.0% of the gross sales price per common unit sold under this at-the-market program. Crestwood Midstream did not issue any common units under this equity distribution program as of March 31, 2015 and through the date of this filing.

Other

In August 2012, Legacy Inergy contributed its retail propane operations to Suburban Propane Partners, L.P. (SPH). In connection with this contribution, Legacy Inergy retained approximately 142,000 SPH units which we record at fair value each quarter. The change in fair value is reflected in the consolidated statements of partners’ capital and the consolidated statements of comprehensive income.

Equity Plans

3 Months Ended

Mar. 31, 2015

Equity [Abstract]

Long-Term Incentive Plans

Equity Plans

Long-term incentive awards are granted under the Crestwood Equity Partners LP Long Term Incentive Plan (Crestwood LTIP) and the Crestwood Midstream Partners LP Long Term Incentive Plan (Crestwood Midstream LTIP) in order to align the economic interests of key employees and directors with those of CEQP and Crestwood Midstream's common unitholders and to provide an incentive for continuous employment. Long-term incentive compensation consist of grants of restricted and phantom units which vest based upon continued service.

Crestwood LTIP

The following table summarizes information regarding restricted and phantom unit activity during the three months ended March 31, 2015:



	Units		Weighted-Average Grant Date Fair Value
Unvested - January 1, 2015	1,315,880		$	13.21
Vested - restricted units	(743,252	)	$	12.96
Granted - restricted units	1,157,174		$	6.80
Granted - phantom units	362,872		$	6.72
Forfeited⁽¹⁾	(69,122	)	$	10.52
Unvested - March 31, 2015	2,023,552		$	8.56

(1) We implemented a company-wide initiative to reduce operating costs in 2015 and beyond, which included a reduction in work force. As a result, 36,542 restricted units were forfeited during the three months ended March 31, 2015.

As of March 31, 2015 and December 31, 2014, we had total unamortized compensation expense of approximately $14.1 million and $8.1 million related to restricted and phantom units, which we expect will be amortized during the next three years (or sooner in certain cases, which generally represents the original vesting period of these instruments), except for grants to non-employee directors of our general partner, which vest over one year. We recognized compensation expense of approximately $2.8 million and $2.5 million (including $2.2 million and $1.7 million that was allocated to Crestwood Midstream) under the Crestwood LTIP during the three months ended March 31, 2015 and 2014, which is included in general and administrative expenses on our consolidated statements of operations. We granted restricted and phantom units with a grant date fair value of approximately $7.9 million and $2.4 million during the three months ended March 31, 2015. As of March 31, 2015, we had 12,713,653 units available for issuance under the Crestwood LTIP.

Crestwood Restricted Units. Under the Crestwood LTIP, participants who have been granted restricted units may elect to have us withhold common units to satisfy minimum statutory tax withholding obligations arising in connection with the vesting of non-vested common units. Any such common units withheld are returned to the Crestwood LTIP on the applicable vesting dates, which correspond to the times at which income is recognized by the employee. When we withhold these common units, we are required to remit to the appropriate taxing authorities the fair value of the units withheld as of the vesting date. The number of units withheld is determined based on the closing price per common unit as reported on the NYSE on such dates. During the three months ended March 31, 2015 and 2014, we withheld 242,365 and 47,800 common units to satisfy employee tax withholding obligations.

Crestwood Phantom Units. The Crestwood LTIP currently permits, and our general partner has made, grants of phantom units. Each phantom unit entitles the holder thereof to receive upon vesting one common unit of us granted pursuant to the Crestwood LTIP and a phantom unit award agreement (the Crestwood Equity Phantom Unit Agreement). The Crestwood Equity Phantom Unit Agreement provides for vesting to occur at the end of three years following the grant date or, if earlier, upon the named executive officer's termination without cause or due to death or disability or the named executive officer's resignation for employee cause (each, as defined in the Crestwood Equity Phantom Unit Agreement). In addition, the Crestwood Equity Phantom Unit Agreement provides for distribution equivalent rights with respect to each phantom unit which are paid in additional phantom units and settled in common units upon vesting of the underlying phantom units.

Crestwood Midstream LTIP

The following table summarizes information regarding restricted and phantom unit activity during the three months ended March 31, 2015:



	Units		Weighted-Average Grant Date Fair Value
Unvested - January 1, 2015	834,796		$	23.18
Vested - restricted units	(424,653	)	$	23.11
Granted - restricted units	512,404		$	16.01
Granted - phantom units	161,039		$	16.02
Forfeited⁽¹⁾	(37,997	)	$	20.93
Unvested - March 31, 2015	1,045,589		$	18.68

(1) We implemented a company-wide initiative to reduce operating costs in 2015 and beyond, which included a reduction in work force. As a result, 21,583 restricted units were forfeited during the three months ended March 31, 2015.

As of March 31, 2015 and December 31, 2014, we had total unamortized compensation expense of approximately $15.7 million and $9.5 million related to restricted and phantom units issued under the Crestwood Midstream LTIP, which we expect will be amortized during the next three years (or sooner in certain cases, which generally represents the original vesting period of these instruments), except for grants to non-employee directors of the general partner of CEQP, which vest over one year. Crestwood Midstream recognized compensation expense of approximately $3.0 million and $2.9 million during the three months ended March 31, 2015 and 2014, which is included in general and administrative expenses on our consolidated statements of operations. We granted restricted and phantom units with a grant date fair value of approximately $8.2 million and $2.6 million during the three months ended March 31, 2015. As of March 31, 2015, we had 17,199,153 units available for issuance under the Crestwood Midstream LTIP.

Crestwood Midstream Restricted Units. Under the Crestwood Midstream LTIP, participants who have been granted restricted units may elect to have common units withheld to satisfy minimum statutory tax withholding obligations arising in connection with the vesting of non-vested common units. Any such common units withheld are returned to the Crestwood Midstream LTIP on the applicable vesting dates, which correspond to the times at which income is recognized by the employee. When such common units are withheld, Crestwood Midstream is required to remit to the appropriate taxing authorities the fair value of the units withheld as of the vesting date. The number of units withheld is determined based on the closing price per common unit as reported on the NYSE on such dates. During the three months ended March 31, 2015 and 2014, Crestwood Midstream withheld 134,591 and 7,456 common units to satisfy employee tax withholding obligations.

Crestwood Midstream Phantom Units. The Crestwood Midstream LTIP currently permits, and Crestwood Midstream's general partner has made, grants of phantom units. Each phantom unit entitles the holder thereof to receive upon vesting one common unit of CMLP granted pursuant to the Crestwood Midstream LTIP and a phantom unit award agreement (the Phantom Unit Agreement). The Phantom Unit Agreement provides for vesting to occur at the end of three years following the grant date (or, if earlier, upon the named executive officer's termination without cause or due to death or disability or the named executive officer's resignation for employee cause (each, as defined in the Phantom Unit Agreement). In addition, the Phantom Unit Agreement provides for distribution equivalent rights with respect to each phantom unit which are paid in additional phantom units and settled in common units upon vesting of the underlying phantom units.

Crestwood Midstream Employee Unit Purchase Plan

Crestwood Midstream has an employee unit purchase plan under which employees of the general partner may purchase Crestwood Midstream's common units through payroll deductions up to a maximum of 10% of the employees' eligible compensation. Under the plan, Crestwood Midstream may purchase its common units on the open market for the benefit of participating employees based on their payroll deductions. In addition, Crestwood Midstream may contribute an additional 10% of participating employees' payroll deductions to purchase additional Crestwood Midstream common units for participating employees. Unless increased by the board of directors of Crestwood Midstream's general partner, the maximum number of units that may be purchased under the plan is 200,000. During the three months ended March 31, 2015, there were 2,011 common units purchased through the employee unit purchase plan related to the fourth quarter of 2014. In April 2015, there were 3,841 common units purchased related to the first quarter of 2015.

- Definition

The entire disclosure for shareholders' equity comprised of portions attributable to the parent entity and noncontrolling interest, including other comprehensive income. Includes, but is not limited to, balances of common stock, preferred stock, additional paid-in capital, other capital and retained earnings, accumulated balance for each classification of other comprehensive income and amount of comprehensive income.

+ References

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+ Details

Commitments and Contingencies	3 Months Ended
Commitments and Contingencies	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Legal Proceedings Property Taxes. In conjunction with the sale of our interest in Tres Palacios to Tres Holdings, we retained the liability of Tres Palacios for certain tax matters, including the property taxes litigation in which we challenged the Matagorda County Appraisal District that the assessed value was over the market value for the tax years 2012 and 2013. For those years, we believe the total difference in taxes between the assessed value and the market value is approximately $12 million. These lawsuits remain pending and the outcome is not yet determined. In January 2015, we settled the lawsuit related to the 2011 tax year with the Matagorda County Appraisal District. Canadian Class Action Lawsuit. Prior to the completion of our acquisition of Arrow on November 8, 2013, a train transporting over 50,000 barrels of crude oil produced in North Dakota derailed in Lac Megantic, Quebec, Canada on July 6, 2013. The derailment resulted in the death of 47 people, injured numerous others, and caused severe damage to property and the environment. In October 2013, certain individuals suffering harm in the derailment filed a motion to certify a class action lawsuit in the Superior Court for the District of Megantic, Province of Quebec, Canada, on behalf of all persons suffering loss in the derailment (the Class Action Suit). In March 2014, the plaintiffs filed their fourth amended motion to name Arrow and numerous other energy companies as additional defendants in the class action lawsuit. The plaintiffs have named at least 53 defendants purportedly involved in the events leading up to the derailment, including the producers and sellers of the crude being transported, the midstream companies that transported the crude from the well head to the rail system, the manufacturers of the rail cars used to transport the crude, the railroad companies involved, the insurers of these companies, and the Canadian Attorney General. The plaintiffs allege, among other things, that Arrow (i) was a producer of the crude oil being transported on the derailed train, (ii) was negligent in failing to properly classify the crude delivered to the trucks that hauled the crude to the rail loading terminal, and (iii) owed a duty to the petitioners to ensure the safe transportation of the crude being transported. The motion to authorize the class action and motions in opposition were heard by the Court in June 2014. We anticipate a ruling from the Judge on the Petitioners' motion to authorize the class action in the first half of 2015. There are three other lawsuits related to the Class Action Suit. Montreal Main & Atlantic Railway filed bankruptcy actions in both the U.S. Bankruptcy Court for the District of Maine and in the Canadian Bankruptcy Court. In addition, a lawsuit was filed in Cook County, Illinois on behalf of the deceased claimants, which is currently stayed due to the bankruptcy proceeding. We are not currently named as a defendant in these additional lawsuits; however, we have been notified by the bankruptcy trustees of a proposal to contribute to a settlement in exchange for a release from all claims related to the Class Action Suit. We have evaluated this proposal and made a confidential contingent offer to the Bankruptcy Trustee. We will vigorously defend ourselves and, to the extent this action proceeds, we believe we have meritorious defenses to the claims. Because these related actions are in the early stages of the proceeding, we are unable to estimate a reasonably possible loss or range of loss in this matter. We also believe these claims are insurable under our insurance policy and we have notified our insurance company of them. When we were served with the Class Action Suit, we notified the former owners of the Arrow system that the claims alleged in the Class Action Suit would, if true, result in breaches of certain representations and warranties made by the former sellers in the agreement under which we acquired Arrow. As part of the acquisition, we deposited 3,309,797 of our common units into an escrow account to cover potential indemnification claims made by us on or before December 31, 2014. Subject to indemnification claims paid out with escrowed units and any outstanding claims outstanding at year end, all common units remaining in the escrow account on January 1, 2015 were to be released to the former owners. In December 2014, we notified the escrow agent of our indemnification notices delivered to the former owners and instructed the escrow agent not to release any escrowed units to the former owners. On February 19, 2015, we received a summons for an action filed against us in the Supreme Court of the State of New York (County of New York), under which the former owners have asserted our indemnification notices regarding the Class Action Suit and our notice to the escrow agent breach the terms of the merger and escrow agreements and the implied covenant of good faith and fair dealing. The former owners have requested declaratory and injunctive relief, as well as monetary damages. Although our insurance policies would not cover this action, we believe we have meritorious defenses to this lawsuit and will aggressively defend ourselves. We are unable to estimate a reasonably possible loss or range of loss in this matter due to the recent filing of this lawsuit. General. We are periodically involved in litigation proceedings. If we determine that a negative outcome is probable and the amount of loss is reasonably estimable, then we accrue the estimated amount. The results of litigation proceedings cannot be predicted with certainty. We could incur judgments, enter into settlements or revise our expectations regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations or cash flows in the period in which the amounts are paid and/or accrued. As of March 31, 2015 and December 31, 2014, we had $1.0 million accrued for our outstanding legal matters. Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures for which we can estimate will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures. Any loss estimates are inherently subjective, based on currently available information, and are subject to management's judgment and various assumptions. Due to the inherently subjective nature of these estimates and the uncertainty and unpredictability surrounding the outcome of legal proceedings, actual results may differ materially from any amounts that have been accrued. Regulatory Compliance In the ordinary course of our business, we are subject to various laws and regulations. In the opinion of our management, compliance with current laws and regulations will not have a material effect on its results of operations, cash flows or financial condition. Environmental Compliance During 2014, we experienced three releases totaling approximately 28,000 barrels of produced water on our Arrow water gathering system located on the Fort Berthold Indian Reservation in North Dakota. We immediately notified the National Response Center, the Three Affiliated Tribes and numerous other regulatory authorities, and thereafter contained and cleaned up the releases completely and placed the impacted segments of these water lines back into service. We will continue our remediation efforts to ensure the impacted lands are restored to their prior state. We believe these releases are insurable events under our policies, and we have notified our carriers of these events. We have not recorded an insurance receivable as of March 31, 2015. In May 2015, we experienced a release of up to 8,000 barrels of produced water on our Arrow water gathering system, and immediately notified numerous regulatory authorities and other third parties. We are currently evaluating the extent of the release and its impact on the related lands, and because this matter is in the early stages of investigation, we are unable to estimate a reasonably possible loss or range of loss. We may potentially be subject to fines and penalties as a result of the water releases. We received data requests from the Environmental Protection Agency (EPA) related to the releases in October 2014, responded to the EPA’s original request for information in January 2015, and are working to respond to supplemental requests received from the EPA in the first quarter of 2015. On April 16, 2015, the EPA issued a Notice of Potential Violation relating to the water releases, and we anticipate responding to the Notice of Potential Violation in May 2015. On March 3, 2015, we received a grand jury subpoena from the United States Attorney’s Office in Bismarck, North Dakota, seeking documents and information relating to the largest of the three releases, and we are in the process of providing the requested information. We cannot predict what the outcome of these investigations will be, and we had no amounts accrued for fines or penalties as of March 31, 2015. Our operations are subject to stringent and complex laws and regulations pertaining to health, safety, and the environment. We are subject to laws and regulations at the federal, state and local levels that relate to air and water quality, hazardous and solid waste management and disposal and other environmental matters. The cost of planning, designing, constructing and operating our facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures. At March 31, 2015 and December 31, 2014, our accrual of approximately $0.3 million and $1.1 million was primarily related to the Arrow water releases described above, which is based on our undiscounted estimate of amounts we will spend on compliance with environmental and other regulations. We estimate that our potential liability for reasonably possible outcomes related to our environmental exposures (including the Arrow water releases described above) could range from approximately $0.3 million to $0.8 million. Self-Insurance We utilize third-party insurance subject to varying retention levels of self-insurance, which management considers prudent. Such self-insurance relates to losses and liabilities primarily associated with medical claims, workers' compensation claims and general, product, vehicle and environmental liability. At March 31, 2015 and December 31, 2014, our self-insurance reserves were $12.8 million and $14.6 million. We estimate that $9.7 million of this balance will be paid subsequent to December 31, 2015. As such, $9.7 million has been classified in other long-term liabilities on our consolidated balance sheets. For more information, see our 2014 Annual Report on Form 10-K filed with the SEC. Contingent Consideration - Antero In connection with the acquisition of Antero Resources Appalachian Corporation (Antero), we agreed to pay Antero conditional consideration in the form of potential additional cash payments of up to $40.0 million, depending on the achievement of certain defined average annual production levels achieved during 2012, 2013 and 2014. In February 2015, we paid Antero $40.0 million to settle the liability under the earn-out provision. This amount is reflected in changes in operating assets and liabilities, net of effects from acquisitions under operating activities in our consolidated statements of cash flows.

Related Party Transactions

3 Months Ended

Mar. 31, 2015

Related Party Transactions

We enter into transactions with our affiliates within the ordinary course of business and the services are based on the same terms as non-affiliates, including gas gathering and processing services under long-term contracts, product purchases and various operating agreements.

The following table shows revenues, costs of goods sold and reimbursements of general and administrative expenses from our affiliates for the three months ended March 31, 2015 and 2014 (in millions):



	Three Months Ended
	March 31,
	2015		2014
Gathering and processing revenues	$	1.0	$	0.9
Gathering and processing costs of product/services sold⁽¹⁾	$	8.3	$	11.0
Reimbursement of general and administrative expenses	$	0.1	$	0.1
Reimbursement of operations and maintenance expenses	$	0.9	$	—


(1)	Represents natural gas purchases from Sabine Oil and Gas LLC.

The following table shows accounts receivable and account payable from our affiliates as of March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015		December 31, 2014
Accounts receivable	$	1.2	$	0.6
Accounts payable	$	5.2	$	5.6

For additional information regarding our related party transactions, see our 2014 Annual Report on Form 10-K filed with the SEC.

- Definition

The entire disclosure for related party transactions. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

+ References + Details

Segments

3 Months Ended

Mar. 31, 2015

Segment Reporting [Abstract]

Segments

Financial Information

We have three operating and reportable segments: (i) gathering and processing operations; (ii) storage and transportation operations; and (iii) NGL and crude services operations. Our gathering and processing operations engage in the gathering, processing, treating, compression, transportation and sales of natural gas and the delivery of NGLs. Our storage and transportation operations provide regulated natural gas storage and transportation services to producers, utilities and other customers. Our NGL and crude services operations provide NGL processing and fractionation, NGLs and crude oil gathering, storage, marketing and transportation, supply and logistics services to producers, refiners, marketers, and other customers that effectively provide flow assurances to our customers, as well as the production and sale of salt products. Our corporate operations include all general and administrative expenses that are not allocated to our reportable segments. We assess the performance of our operating segments based on EBITDA, which represents operating income plus depreciation, amortization and accretion expense.

Below is a reconciliation of net income to EBITDA (in millions):



	Three Months Ended
	March 31,
	2015		2014
Net income	$	18.1	$	13.2
Add:
Interest and debt expense, net	33.6		31.7
Provision for income taxes	0.4		0.8
Depreciation, amortization and accretion	74.2		66.3
EBITDA	$	126.3	$	112.0

The following tables summarize the reportable segment data for the three months ended March 31, 2015 and 2014 (in millions).



	Three Months Ended March 31, 2015
	Gathering and Processing			Storage and Transportation			NGL and Crude Services		Intersegment			Corporate			Total
Revenues	$	78.5		$	45.7		$	607.5	$	(0.2	)	$	—		$	731.5
Costs of product/services sold	12.7			3.3			513.9		(0.2		)	—			529.7
Operations and maintenance expense	14.9			4.3			31.4		—			—			50.6
General and administrative expense	—			—			—		—			27.5			27.5
Loss on long-lived assets	(0.3		)	(0.7		)	—		—			—			(1.0		)
Earnings from unconsolidated affiliates, net	2.5			0.9			—		—			—			3.4
Other income, net	—			—			—					0.2			0.2
EBITDA	$	53.1		$	38.3		$	62.2	$	—		$	(27.3	)	$	126.3
Goodwill	$	338.3		$	726.3		$	1,427.2	$	—		$	—		$	2,491.8
Total assets	$	2,617.1		$	1,976.1		$	3,570.3	$	—		$	184.7		$	8,348.2
Purchases of property, plant and equipment	$	11.4		$	2.7		$	33.1	$	—		$	0.2		$	47.4



	Three Months Ended March 31, 2014
	Gathering and Processing			Storage and Transportation		NGL and Crude Services			Intersegment		Corporate			Total
Revenues	$	79.5		$	51.0	$	841.1		$	—	$	—		$	971.6
Costs of product/services sold	18.7			6.8		760.5			—		—			786.0
Operations and maintenance expense	13.4			6.2		24.5			—		—			44.1
General and administrative expense	—			—		—			—		27.9			27.9
Gain on long-lived assets	0.5			—		—			—		—			0.5
Loss on contingent consideration	(2.1		)	—		—			—		—			(2.1		)
Earnings (loss) from unconsolidated affiliates, net	0.3			—		(0.4		)	—		—			(0.1		)
Other income, net	—			—		—			—		0.1			0.1
EBITDA	$	46.1		$	38.0	$	55.7		$	—	$	(27.8	)	$	112.0
Goodwill	$	356.8		$	728.6	$	1,463.2		$	—	$	—		$	2,548.6
Total assets	$	2,547.8		$	2,162.7	$	3,582.1		$	—	$	187.9		$	8,480.5
Purchases of property, plant and equipment	$	46.3		$	1.6	$	30.9		$	—	$	3.6		$	82.4

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 34
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8981-108599

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9038-108599

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 33
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8971-108599

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8595-108599

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8380-108599

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8933-108599

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 26
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8844-108599

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 35
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8984-108599

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9031-108599

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9054-108599

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8538-108599

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 29
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8864-108599

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8924-108599

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8906-108599

+ Details

Condensed Consolidating Financial Information

3 Months Ended

Mar. 31, 2015

Text Block [Abstract]

Condensed Consolidating Financial Information

We are a holding company and own no operating assets and have no significant operations independent of our subsidiaries. Obligations under the CEQP Senior Notes and the CEQP Credit Facility are jointly and severally guaranteed by our wholly owned subsidiaries. Legacy Crestwood GP and Crestwood Midstream and its wholly owned subsidiaries (collectively, Non-Guarantor Subsidiaries) do not guarantee our obligations under CEQP Senior Notes or CEQP Credit Facility. CEQP Finance Corp., the co-issuer of the CEQP Senior Notes, is our 100% owned subsidiary and has no material assets, operations, revenues or cash flows other than those related to its service as co-issuer of our senior notes.

As summarized in the table below, the condensed consolidating financial statements for the three months ended March 31, 2014 have been corrected for certain errors in presentation. There was no impact to our consolidated statement of operations or our consolidated statement of cash flows for the three months ended March 31, 2014.



	Parent					Guarantor Subsidiaries				Eliminations
	As Adjusted			As Previously Reported		As Adjusted		As Previously Reported		As Adjusted			As Previously Reported
	(in millions)
General and administrative expense	$	2.8		$	—	$	1.0	$	3.8	$	—		$	—
Operating income (loss)	(2.8		)	—		18.9		16.1		—			—
Equity in net income (loss) of subsidiary	19.6			16.8		—		—		(19.6		)	(16.8		)
Income (loss) before income taxes	13.2			13.2		19.0		16.2		(19.6		)	(16.8		)
Net income (loss)	13.2			13.2		18.9		16.1		(19.6		)	(16.8		)
Net income (loss) attributable to partners	13.2			13.2		18.9		16.1		(19.6		)	(16.8		)



	Parent						Guarantor Subsidiaries						Eliminations
	As Adjusted			As Previously Reported			As Adjusted			As Previously Reported			As Adjusted			As Previously Reported
	(in millions)
Cash flows from operating activities:	$	(6.9	)	$	—		$	21.1		$	14.2		$	—		$	—

Cash flows from investing activities:
Purchases of property, plant and equipment	(2.7		)	—			(2.4		)	(5.1		)	—			—
Capital contributions from consolidated affiliates and other	10.5			36.1			—			10.5			(10.5		)	(46.6		)
Net cash provided by (used in) investing activities	7.8			36.1			(2.4		)	5.4			(10.5		)	(46.6		)

Cash flows from financing activities:
Proceeds from the issuance of long-term debt	190.4			—			—			190.4			—			—
Principal payments on long-term debt	(183.8		)	—			—			(183.8		)	—			—
Distributions paid to partners	(25.6		)	(36.1		)	—			(25.6		)	10.5			46.6
Change in intercompany balances	18.1			—			(18.1		)	—			—			—
Net cash provided by (used in) financing activities	(0.9		)	(36.1		)	(18.5		)	(19.4		)	10.5			46.6

The tables below present condensed consolidating financial statements for us (parent) on a stand-alone, unconsolidated basis, and our combined guarantor and combined non-guarantor subsidiaries as of March 31, 2015 and December 31, 2014, and for the three months ended March 31, 2015 and 2014. 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
March 31, 2015
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	0.9	$	—	$	66.8	$	—		$	67.7

Accounts receivable	—		97.1		191.5		—			288.6
Accounts receivable - related party	—		0.1		1.1		—			1.2
Accounts receivable - intercompany	2.8		—		—		(2.8		)	—
Total accounts receivable	2.8		97.2		192.6		(2.8		)	289.8

Inventories	—		14.7		9.2		—			23.9
Other current assets	—		33.8		23.6		—			57.4
Total current assets	3.7		145.7		292.2		(2.8		)	438.8

Property, plant and equipment, net	2.9		225.3		3,649.5		—			3,877.7
Goodwill and intangible assets, net	1.4		703.2		3,000.7		—			3,705.3
Investment in consolidated affiliates	5,829.5		—		—		(5,829.5		)	—
Investment in unconsolidated affiliates	—		—		316.6		—			316.6
Other assets	—		8.6		1.2		—			9.8
Total assets	$	5,837.5	$	1,082.8	$	7,260.2	$	(5,832.3	)	$	8,348.2

Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	90.4	$	123.1	$	—		$	213.5
Accounts payable - related party	—		2.5		2.7		—			5.2
Accounts payable - intercompany	—		—		2.8		(2.8		)	—
Total accounts payable	—		92.9		128.6		(2.8		)	218.7

Other current liabilities	—		29.6		93.1		—			122.7
Total current liabilities	—		122.5		221.7		(2.8		)	341.4

Long-term liabilities:
Long-term debt, less current portion	321.1		—		2,121.7		—			2,442.8
Other long-term liabilities	11.5		16.1		31.5		—			59.1

Partners' capital	758.0		944.2		138.4		(1,082.6		)	758.0
Interest of non-controlling partners in subsidiaries	4,746.9		—		4,746.9		(4,746.9		)	4,746.9
Total partners' capital	5,504.9		944.2		4,885.3		(5,829.5		)	5,504.9
Total liabilities and partners' capital	$	5,837.5	$	1,082.8	$	7,260.2	$	(5,832.3	)	$	8,348.2



Condensed Consolidating Balance Sheet
December 31, 2014
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	3.7	$	0.5	$	4.6	$	—		$	8.8

Accounts receivable	—		137.5		241.5		—			379.0
Accounts receivable - related party	—		0.3		0.3		—			0.6
Accounts receivable - intercompany	3.2		—		—		(3.2		)	—
Total accounts receivable	3.2		137.8		241.8		(3.2		)	379.6

Inventories	—		38.6		8.0		—			46.6
Other current assets	—		84.4		18.7		—			103.1
Total current assets	6.9		261.3		273.1		(3.2		)	538.1

Property, plant and equipment, net	2.5		227.1		3,664.2		—			3,893.8
Goodwill and intangible assets, net	1.7		706.7		3,014.7		—			3,723.1
Investment in consolidated affiliates	5,971.2		—		—		(5,971.2		)	—
Investment in unconsolidated affiliates	—		—		295.1		—			295.1
Other assets	—		9.9		1.4		—			11.3
Total assets	$	5,982.3	$	1,205.0	$	7,248.5	$	(5,974.4	)	$	8,461.4

Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	109.5	$	126.1	$	—		$	235.6
Accounts payable - related party	—		2.5		3.1		—			5.6
Accounts payable - intercompany	—		—		3.2		(3.2		)	—
Total accounts payable	—		112.0		132.4		(3.2		)	241.2

Other current liabilities	4.9		56.1		122.7		—			183.7
Total current liabilities	4.9		168.1		255.1		(3.2		)	424.9

Long-term liabilities:
Long-term debt, less current portion	380.0		—		2,012.8		—			2,392.8
Other long-term liabilities	12.9		15.1		31.2		—			59.2

Partners' capital	776.2		1,021.8		141.1		(1,162.9		)	776.2
Interest of non-controlling partners in subsidiaries	4,808.3		—		4,808.3		(4,808.3		)	4,808.3
Total partners' capital	5,584.5		1,021.8		4,949.4		(5,971.2		)	5,584.5
Total liabilities and partners' capital	$	5,982.3	$	1,205.0	$	7,248.5	$	(5,974.4	)	$	8,461.4



Condensed Consolidating Statements of Operations
Three Months Ended March 31, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	280.0		$	455.1		$	(3.6	)	$	731.5

Costs of product/services sold	—			246.7			286.6			(3.6		)	529.7
Expenses:
Operations and maintenance	—			15.5			35.1			—			50.6
General and administrative	1.9			1.4			24.2			—			27.5
Depreciation, amortization and accretion	—			9.8			64.4			—			74.2
	1.9			26.7			123.7			—			152.3
Other operating income (expense):
Loss on long-lived assets, net	—			(0.2		)	(0.8		)	—			(1.0		)
Operating income (loss)	(1.9		)	6.4			44.0			—			48.5
Earnings from unconsolidated affiliates, net	—			—			3.4			—			3.4
Interest and debt expense, net	(3.7		)	—			(29.9		)	—			(33.6		)
Other income, net	—			0.2			—			—			0.2
Equity in net income of subsidiary	23.8			—			—			(23.8		)	—
Income (loss) before income taxes	18.2			6.6			17.5			(23.8		)	18.5
Provision for income taxes	0.1			—			0.3			—			0.4
Net income (loss)	18.1			6.6			17.2			(23.8		)	18.1
Net income attributable to non-controlling partners in subsidiaries	—			—			(9.8		)	—			(9.8		)
Net income (loss) attributable to partners	$	18.1		$	6.6		$	7.4		$	(23.8	)	$	8.3



Condensed Consolidating Statements of Operations
Three Months Ended March 31, 2014
(in millions)
	Parent			Guarantor Subsidiaries		Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	437.9	$	537.0		$	(3.3	)	$	971.6

Costs of product/services sold	—			391.2		398.1			(3.3		)	786.0
Expenses:
Operations and maintenance	—			16.1		28.0			—			44.1
General and administrative	2.8			1.0		24.1			—			27.9
Depreciation, amortization and accretion	—			10.7		55.6			—			66.3
	2.8			27.8		107.7			—			138.3
Other operating income (expense):
Gain on long-lived assets, net	—			—		0.5			—			0.5
Loss on contingent consideration	—			—		(2.1		)	—			(2.1		)
Operating income (loss)	(2.8		)	18.9		29.6			—			45.7
Loss from unconsolidated affiliates, net	—			—		(0.1		)	—			(0.1		)
Interest and debt expense, net	(3.6		)	—		(28.1		)	—			(31.7		)
Other income, net	—			0.1		—			—			0.1
Equity in net income of subsidiary	19.6			—		—			(19.6		)	—
Income (loss) before income taxes	13.2			19.0		1.4			(19.6		)	14.0
Provision for income taxes	—			0.1		0.7			—			0.8
Net income (loss)	13.2			18.9		0.7			(19.6		)	13.2
Net loss attributable to non-controlling partners in subsidiary	—			—		6.4			—			6.4
Net income (loss) attributable to partners	$	13.2		$	18.9	$	7.1		$	(19.6	)	$	19.6



Condensed Consolidating Statements of Comprehensive Income
Three Months Ended March 31, 2015
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Net income (loss)	$	18.1	$	6.6	$	17.2	$	(23.8	)	$	18.1
Change in fair value of Suburban Propane Partners LP units	—		—		—		—			—
Comprehensive income (loss)	$	18.1	$	6.6	$	17.2	$	(23.8	)	$	18.1



Condensed Consolidating Statements of Comprehensive Income
Three Months Ended March 31, 2014
(in millions)
	Parent			Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Net income (loss)	$	13.2		$	18.9	$	0.7	$	(19.6	)	$	13.2
Change in fair value of Suburban Propane Partners LP units	(0.8		)	—		—		—			(0.8		)
Comprehensive income (loss)	$	12.4		$	18.9	$	0.7	$	(19.6	)	$	12.4



Condensed Consolidating Statements of Cash Flows
Three Months Ended March 31, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:	$	(5.4	)	$	85.0		$	77.0		$	—		$	156.6

Cash flows from investing activities:
Purchases of property, plant and equipment	(0.1		)	(4.0		)	(43.3		)	—			(47.4		)
Investment in unconsolidated affiliates	(0.2		)	—			(17.9		)	—			(18.1		)
Proceeds from sale of assets	—			0.2			0.3			—			0.5
Capital contribution from consolidated affiliates, net	10.5			—			—			(10.5		)	—
Other	(0.2		)	—			—			—			(0.2		)
Net cash provided by (used in) investing activities	10.0			(3.8		)	(60.9		)	(10.5		)	(65.2		)

Cash flows from financing activities:
Proceeds from the issuance of long-term debt	138.1			—			1,114.6			—			1,252.7
Principal payments on long-term debt	(199.9		)	—			(970.0		)	—			(1,169.9		)
Payments on capital leases	—			—			(0.7		)	—			(0.7		)
Payments for debt-related deferred costs	—			—			(11.1		)	—			(11.1		)
Distributions paid to partners	(25.8		)	—			(10.5		)	10.5			(25.8		)
Distributions paid to non-controlling partners	—			—			(74.3		)	—			(74.3		)
Taxes paid for unit-based compensation vesting	—			(1.4		)	(1.7		)	—			(3.1		)
Change in intercompany balances	80.2			(80.2		)	—			—			—
Other	—			(0.1		)	(0.2		)	—			(0.3		)
Net cash provided by (used in) financing activities	(7.4		)	(81.7		)	46.1			10.5			(32.5		)

Net change in cash	(2.8		)	(0.5		)	62.2			—			58.9
Cash at beginning of period	3.7			0.5			4.6			—			8.8
Cash at end of period	$	0.9		$	—		$	66.8		$	—		$	67.7



Condensed Consolidating Statements of Cash Flows
Three Months Ended March 31, 2014
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:	$	(6.9	)	$	21.1		$	67.7		$	—		$	81.9

Cash flows from investing activities:
Acquisitions, net of cash acquired	—			—			(12.1		)	—			(12.1		)
Purchases of property, plant and equipment	(2.7		)	(2.4		)	(77.3		)	—			(82.4		)
Investment in unconsolidated affiliates	—			—			(19.8		)	—			(19.8		)
Capital contribution from consolidated affiliates	10.5			—			—			(10.5		)	—
Net cash provided by (used in) investing activities	7.8			(2.4		)	(109.2		)	(10.5		)	(114.3		)

Cash flows from financing activities:
Proceeds from the issuance of long-term debt	190.4			—			306.0			—			496.4
Principal payments on long-term debt	(183.8		)	—			(188.8		)	—			(372.6		)
Distributions paid to partners	(25.6		)	—			(10.5		)	10.5			(25.6		)
Distributions paid to non-controlling partners	—			—			(74.1		)	—			(74.1		)
Net proceeds from issuance of preferred equity of subsidiary	—			—			12.3			—			12.3
Change in intercompany balances	18.1			(18.1		)	—			—			—
Other	—			(0.4		)	(1.1		)	—			(1.5		)
Net cash provided by (used in) financing activities	(0.9		)	(18.5		)	43.8			10.5			34.9

Net change in cash	—			0.2			2.3			—			2.5
Cash at beginning of period	0.1			2.4			2.7			—			5.2
Cash at end of period	$	0.1		$	2.6		$	5.0		$	—		$	7.7

Basis of Presentation and Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
Significant Accounting Policies	Significant Accounting Policies There were no material changes in our significant accounting policies from those described in our 2014 Annual Report on Form 10-K.
New Accounting Pronouncements Issued But Not Yet Adopted	New Accounting Pronouncements Issued But Not Yet Adopted As of March 31, 2015, the following accounting standards had not yet been adopted by us. In May 2014, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update 2014-09, Revenue from Contracts with Customers, which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes current revenue recognition guidance. We expect to adopt the provisions of this standard effective January 1, 2017 and are currently evaluating the impact that this standard will have on our consolidated financial statements. In April 2015, the FASB proposed deferring the effective date of this standard by one year. In February 2015, the FASB issued Accounting Standards Update 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis, which provides additional guidance on the consolidation of limited partnerships and on the evaluation of variable interest entities. We expect to adopt the provisions of this standard effective January 1, 2016 and are currently evaluating the impact, if any, that this standard may have on our consolidated financial statements. In April 2015, the FASB issued Accounting Standards Update 2015-03, Interest - Imputation of Interest (Subtopic 835-30), which requires deferred debt issuance costs to be classified as a reduction of the debt liability rather than as an asset in the balance sheet. We expect to adopt the provisions of this standard effective January 1, 2016, and do not currently anticipate it will have a significant impact on our consolidated financial statements.

Certain Balance Sheet Information (Tables)

3 Months Ended

Mar. 31, 2015

Balance Sheet Related Disclosures [Abstract]

Property, Plant And Equipment

Property, plant and equipment consisted of the following at March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015		December 31, 2014
Gathering systems and pipelines	$	1,417.8	$	1,410.9
Facilities and equipment	1,638.0		1,648.3
Buildings, land, rights-of-way, storage contracts and easements	843.5		841.5
Vehicles	46.6		45.2
Construction in process	174.1		156.5
Base gas	37.5		37.5
Salt deposits	120.5		120.5
Office furniture and fixtures	13.7		13.5
	4,291.7		4,273.9
Less: accumulated depreciation and depletion	414.0		380.1
Total property, plant and equipment, net	$	3,877.7	$	3,893.8

Intangible Assets

Intangible assets consisted of the following at March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015		December 31, 2014
Customer accounts	$	583.7	$	583.7
Covenants not to compete	9.6		9.6
Gas gathering, compression and processing contracts	726.1		730.2
Acquired storage contracts	29.0		29.0
Trademarks	32.2		32.2
Deferred financing costs	68.3		57.2
	1,448.9		1,441.9
Less: accumulated amortization	235.4		210.6
Total intangible assets, net	$	1,213.5	$	1,231.3

Schedule of Accrued Liabilities

Accrued expenses and other liabilities consisted of the following at March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015		December 31, 2014
Accrued expenses	$	36.3	$	52.5
Accrued property taxes	4.5		2.2
Accrued product purchases payable	0.4		0.7
Tax payable	—		1.6
Interest payable	14.5		23.5
Accrued additions to property, plant and equipment	9.1		20.0
Commitments and contingent liabilities (Note 12)	—		40.0
Capital leases	1.7		1.9
Deferred revenue	11.3		12.2
Total accrued expenses and other liabilities	$	77.8	$	154.6

Investments in Unconsolidated Affiliates (Tables)

3 Months Ended

Mar. 31, 2015

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments

Our net investments in and earnings (loss) from our unconsolidated affiliates are as follows (in millions, unless otherwise stated):



	Ownership Percentage			Investment				Earnings (Loss) from Unconsolidated Affiliates
	March 31,			March 31,		December 31,		Three Months Ended March 31,
	2015			2015		2014		2015		2014
Jackalope Gas Gathering Services, L.L.C.⁽¹⁾	50.00	%	⁽⁴⁾	$	244.2	$	232.9	$	2.5	$	0.3
Tres Palacios Holdings LLC⁽²⁾	50.01	%		42.8		36.0		0.9		—
Powder River Basin Industrial Complex, LLC⁽³⁾	50.01	%		29.6		26.2		—		(0.4		)
Total				$	316.6	$	295.1	$	3.4	$	(0.1	)

(1)

(2)


(3)	As of March 31, 2015, our investment balance approximated our equity in the underlying net assets of Powder River Basin Industrial Complex, LLC (PRBIC). Our PRBIC investment is included in our NGL and crude services segment.


(4)	Excludes non-controlling interests related to our investment in Jackalope. See Note 10 for a further discussion of our non-controlling interest related to our investment in Jackalope.

Risk Management (Tables)

3 Months Ended

Mar. 31, 2015

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

Notional Amounts And Terms Of Company's Derivative Financial Instruments

The notional amounts and terms of our derivative financial instruments include the following at March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015		December 31, 2014
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, crude and heating oil (barrels)	5.9	6.8	6.8	8.4
Natural gas (MMBTU’s)	—	—	0.2	0.1

Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2015

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

Schedule of Carrying Values and Estimated Fair Values of Debt Instruments



	March 31, 2015				December 31, 2014
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
CEQP Senior Notes	$	10.6	$	10.6	$	11.4	$	11.6
Crestwood Midstream 2019 Senior Notes	$	350.9	$	363.6	$	351.0	$	360.5
Crestwood Midstream 2020 Senior Notes	$	503.8	$	500.3	$	504.0	$	481.6
Crestwood Midstream 2022 Senior Notes	$	600.0	$	607.5	$	600.0	$	568.5
Crestwood Midstream 2023 Senior Notes	$	700.0	$	710.5	$	—	$	—

Assets And Liabilities Measured At Fair Value On Recurring Basis



	March 31, 2015
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Total		Netting Agreements⁽¹⁾			Total
Assets
Assets from price risk management	$	—	$	41.1	$	—	$	41.1	$	(11.6	)	$	29.5
Suburban Propane Partners, L.P. units⁽²⁾	6.1		—		—		6.1		—			6.1
Total assets at fair value	$	6.1	$	41.1	$	—	$	47.2	$	(11.6	)	$	35.6

Liabilities
Liabilities from price risk management	$	0.2	$	35.2	$	—	$	35.4	$	(26.8	)	$	8.6
Interest rate swaps⁽³⁾	—		1.3		—		1.3		—			1.3
Total liabilities at fair value	$	0.2	$	36.5	$	—	$	36.7	$	(26.8	)	$	9.9



	December 31, 2014
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Total		Netting Agreements⁽¹⁾			Total
Assets
Assets from price risk management	$	0.5	$	146.7	$	—	$	147.2	$	(67.4	)	$	79.8
Suburban Propane Partners, L.P. units⁽²⁾	6.1		—		—		6.1		—			6.1
Total assets at fair value	$	6.6	$	146.7	$	—	$	153.3	$	(67.4	)	$	85.9

Liabilities
Liabilities from price risk management	$	1.6	$	99.2	$	—	$	100.8	$	(75.4	)	$	25.4
Interest rate swaps⁽³⁾	—		1.6		—		1.6		—			1.6
Total liabilities at fair value	$	1.6	$	100.8	$	—	$	102.4	$	(75.4	)	$	27.0


(1)	Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions as well as cash collateral held or placed with the same counterparties.


(2)	Our Suburban Propane Partners, L.P. units are included in prepaid expenses and other current assets on our consolidated balance sheets.


(3)	Interest rate swaps are included in other long-term liabilities on our consolidated balance sheets.

Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2015

Text Block [Abstract]

Components Of Long-Term Debt

Long-term debt consisted of the following at March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015		December 31, 2014
CEQP Credit Facility	$	308.0	$	369.0
CEQP Senior Notes	10.6		11.4
Crestwood Midstream Revolver	—		555.0
Crestwood Midstream 2019 Senior Notes	350.0		350.0
Premium on Crestwood Midstream 2019 Senior Notes	0.9		1.0
Crestwood Midstream 2020 Senior Notes	500.0		500.0
Fair value adjustment of Crestwood Midstream 2020 Senior Notes	3.8		4.0
Crestwood Midstream 2022 Senior Notes	600.0		600.0
Crestwood Midstream 2023 Senior Notes	700.0		—
Other	5.8		6.1
Total debt	2,479.1		2,396.5
Less: current portion	36.3		3.7
Total long-term debt	$	2,442.8	$	2,392.8

- Definition

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

+ References

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

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21475-112644

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 470
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6479336&loc=d3e64711-112823

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

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=34725769&loc=d3e28878-108400

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21538-112644

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21506-112644

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28541-108399

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28551-108399

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21521-112644

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph 22
-Article 5

+ Details

Partners' Capital (Tables)

3 Months Ended

Mar. 31, 2015

Statement of Partners' Capital [Abstract]

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

A summary of our limited partner quarterly cash distributions for the three months ended March 31, 2015 and 2014 is presented below:



Record Date	Payment Date	Per Unit Rate		Cash Distributions (in millions)
2015
February 6, 2015	February 13, 2015	$	0.1375	$	25.8
2014
February 7, 2014	February 14, 2014	$	0.1375	$	25.6

Equity Plans (Tables)

3 Months Ended

Mar. 31, 2015

Equity [Abstract]

Disclosure of Share-based Compensation Arrangements by Share-based Payment Award

The following table summarizes information regarding restricted and phantom unit activity during the three months ended March 31, 2015:



	Units		Weighted-Average Grant Date Fair Value
Unvested - January 1, 2015	834,796		$	23.18
Vested - restricted units	(424,653	)	$	23.11
Granted - restricted units	512,404		$	16.01
Granted - phantom units	161,039		$	16.02
Forfeited⁽¹⁾	(37,997	)	$	20.93
Unvested - March 31, 2015	1,045,589		$	18.68

The following table summarizes information regarding restricted and phantom unit activity during the three months ended March 31, 2015:



	Units		Weighted-Average Grant Date Fair Value
Unvested - January 1, 2015	1,315,880		$	13.21
Vested - restricted units	(743,252	)	$	12.96
Granted - restricted units	1,157,174		$	6.80
Granted - phantom units	362,872		$	6.72
Forfeited⁽¹⁾	(69,122	)	$	10.52
Unvested - March 31, 2015	2,023,552		$	8.56

Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2015

Schedule of Related Party Transactions

The following table shows revenues, costs of goods sold and reimbursements of general and administrative expenses from our affiliates for the three months ended March 31, 2015 and 2014 (in millions):



	Three Months Ended
	March 31,
	2015		2014
Gathering and processing revenues	$	1.0	$	0.9
Gathering and processing costs of product/services sold⁽¹⁾	$	8.3	$	11.0
Reimbursement of general and administrative expenses	$	0.1	$	0.1
Reimbursement of operations and maintenance expenses	$	0.9	$	—


(1)	Represents natural gas purchases from Sabine Oil and Gas LLC.

The following table shows accounts receivable and account payable from our affiliates as of March 31, 2015 and December 31, 2014 (in millions):



	March 31, 2015		December 31, 2014
Accounts receivable	$	1.2	$	0.6
Accounts payable	$	5.2	$	5.6

Segments (Tables)

3 Months Ended

Mar. 31, 2015

Segment Reporting [Abstract]

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

Below is a reconciliation of net income to EBITDA (in millions):



	Three Months Ended
	March 31,
	2015		2014
Net income	$	18.1	$	13.2
Add:
Interest and debt expense, net	33.6		31.7
Provision for income taxes	0.4		0.8
Depreciation, amortization and accretion	74.2		66.3
EBITDA	$	126.3	$	112.0

Summary Of Segment Information

The following tables summarize the reportable segment data for the three months ended March 31, 2015 and 2014 (in millions).



	Three Months Ended March 31, 2015
	Gathering and Processing			Storage and Transportation			NGL and Crude Services		Intersegment			Corporate			Total
Revenues	$	78.5		$	45.7		$	607.5	$	(0.2	)	$	—		$	731.5
Costs of product/services sold	12.7			3.3			513.9		(0.2		)	—			529.7
Operations and maintenance expense	14.9			4.3			31.4		—			—			50.6
General and administrative expense	—			—			—		—			27.5			27.5
Loss on long-lived assets	(0.3		)	(0.7		)	—		—			—			(1.0		)
Earnings from unconsolidated affiliates, net	2.5			0.9			—		—			—			3.4
Other income, net	—			—			—					0.2			0.2
EBITDA	$	53.1		$	38.3		$	62.2	$	—		$	(27.3	)	$	126.3
Goodwill	$	338.3		$	726.3		$	1,427.2	$	—		$	—		$	2,491.8
Total assets	$	2,617.1		$	1,976.1		$	3,570.3	$	—		$	184.7		$	8,348.2
Purchases of property, plant and equipment	$	11.4		$	2.7		$	33.1	$	—		$	0.2		$	47.4



	Three Months Ended March 31, 2014
	Gathering and Processing			Storage and Transportation		NGL and Crude Services			Intersegment		Corporate			Total
Revenues	$	79.5		$	51.0	$	841.1		$	—	$	—		$	971.6
Costs of product/services sold	18.7			6.8		760.5			—		—			786.0
Operations and maintenance expense	13.4			6.2		24.5			—		—			44.1
General and administrative expense	—			—		—			—		27.9			27.9
Gain on long-lived assets	0.5			—		—			—		—			0.5
Loss on contingent consideration	(2.1		)	—		—			—		—			(2.1		)
Earnings (loss) from unconsolidated affiliates, net	0.3			—		(0.4		)	—		—			(0.1		)
Other income, net	—			—		—			—		0.1			0.1
EBITDA	$	46.1		$	38.0	$	55.7		$	—	$	(27.8	)	$	112.0
Goodwill	$	356.8		$	728.6	$	1,463.2		$	—	$	—		$	2,548.6
Total assets	$	2,547.8		$	2,162.7	$	3,582.1		$	—	$	187.9		$	8,480.5
Purchases of property, plant and equipment	$	46.3		$	1.6	$	30.9		$	—	$	3.6		$	82.4

Condensed Consolidating Financial Information (Tables)

3 Months Ended

Mar. 31, 2015

Mar. 31, 2014

Text Block [Abstract]

Schedule of Error Corrections and Prior Period Adjustments



	Parent					Guarantor Subsidiaries				Eliminations
	As Adjusted			As Previously Reported		As Adjusted		As Previously Reported		As Adjusted			As Previously Reported
	(in millions)
General and administrative expense	$	2.8		$	—	$	1.0	$	3.8	$	—		$	—
Operating income (loss)	(2.8		)	—		18.9		16.1		—			—
Equity in net income (loss) of subsidiary	19.6			16.8		—		—		(19.6		)	(16.8		)
Income (loss) before income taxes	13.2			13.2		19.0		16.2		(19.6		)	(16.8		)
Net income (loss)	13.2			13.2		18.9		16.1		(19.6		)	(16.8		)
Net income (loss) attributable to partners	13.2			13.2		18.9		16.1		(19.6		)	(16.8		)



	Parent						Guarantor Subsidiaries						Eliminations
	As Adjusted			As Previously Reported			As Adjusted			As Previously Reported			As Adjusted			As Previously Reported
	(in millions)
Cash flows from operating activities:	$	(6.9	)	$	—		$	21.1		$	14.2		$	—		$	—

Cash flows from investing activities:
Purchases of property, plant and equipment	(2.7		)	—			(2.4		)	(5.1		)	—			—
Capital contributions from consolidated affiliates and other	10.5			36.1			—			10.5			(10.5		)	(46.6		)
Net cash provided by (used in) investing activities	7.8			36.1			(2.4		)	5.4			(10.5		)	(46.6		)

Cash flows from financing activities:
Proceeds from the issuance of long-term debt	190.4			—			—			190.4			—			—
Principal payments on long-term debt	(183.8		)	—			—			(183.8		)	—			—
Distributions paid to partners	(25.6		)	(36.1		)	—			(25.6		)	10.5			46.6
Change in intercompany balances	18.1			—			(18.1		)	—			—			—
Net cash provided by (used in) financing activities	(0.9		)	(36.1		)	(18.5		)	(19.4		)	10.5			46.6

Condensed Consolidating Balance Sheet



Condensed Consolidating Balance Sheet
March 31, 2015
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	0.9	$	—	$	66.8	$	—		$	67.7

Accounts receivable	—		97.1		191.5		—			288.6
Accounts receivable - related party	—		0.1		1.1		—			1.2
Accounts receivable - intercompany	2.8		—		—		(2.8		)	—
Total accounts receivable	2.8		97.2		192.6		(2.8		)	289.8

Inventories	—		14.7		9.2		—			23.9
Other current assets	—		33.8		23.6		—			57.4
Total current assets	3.7		145.7		292.2		(2.8		)	438.8

Property, plant and equipment, net	2.9		225.3		3,649.5		—			3,877.7
Goodwill and intangible assets, net	1.4		703.2		3,000.7		—			3,705.3
Investment in consolidated affiliates	5,829.5		—		—		(5,829.5		)	—
Investment in unconsolidated affiliates	—		—		316.6		—			316.6
Other assets	—		8.6		1.2		—			9.8
Total assets	$	5,837.5	$	1,082.8	$	7,260.2	$	(5,832.3	)	$	8,348.2

Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	90.4	$	123.1	$	—		$	213.5
Accounts payable - related party	—		2.5		2.7		—			5.2
Accounts payable - intercompany	—		—		2.8		(2.8		)	—
Total accounts payable	—		92.9		128.6		(2.8		)	218.7

Other current liabilities	—		29.6		93.1		—			122.7
Total current liabilities	—		122.5		221.7		(2.8		)	341.4

Long-term liabilities:
Long-term debt, less current portion	321.1		—		2,121.7		—			2,442.8
Other long-term liabilities	11.5		16.1		31.5		—			59.1

Partners' capital	758.0		944.2		138.4		(1,082.6		)	758.0
Interest of non-controlling partners in subsidiaries	4,746.9		—		4,746.9		(4,746.9		)	4,746.9
Total partners' capital	5,504.9		944.2		4,885.3		(5,829.5		)	5,504.9
Total liabilities and partners' capital	$	5,837.5	$	1,082.8	$	7,260.2	$	(5,832.3	)	$	8,348.2



Condensed Consolidating Balance Sheet
December 31, 2014
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash	$	3.7	$	0.5	$	4.6	$	—		$	8.8

Accounts receivable	—		137.5		241.5		—			379.0
Accounts receivable - related party	—		0.3		0.3		—			0.6
Accounts receivable - intercompany	3.2		—		—		(3.2		)	—
Total accounts receivable	3.2		137.8		241.8		(3.2		)	379.6

Inventories	—		38.6		8.0		—			46.6
Other current assets	—		84.4		18.7		—			103.1
Total current assets	6.9		261.3		273.1		(3.2		)	538.1

Property, plant and equipment, net	2.5		227.1		3,664.2		—			3,893.8
Goodwill and intangible assets, net	1.7		706.7		3,014.7		—			3,723.1
Investment in consolidated affiliates	5,971.2		—		—		(5,971.2		)	—
Investment in unconsolidated affiliates	—		—		295.1		—			295.1
Other assets	—		9.9		1.4		—			11.3
Total assets	$	5,982.3	$	1,205.0	$	7,248.5	$	(5,974.4	)	$	8,461.4

Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	109.5	$	126.1	$	—		$	235.6
Accounts payable - related party	—		2.5		3.1		—			5.6
Accounts payable - intercompany	—		—		3.2		(3.2		)	—
Total accounts payable	—		112.0		132.4		(3.2		)	241.2

Other current liabilities	4.9		56.1		122.7		—			183.7
Total current liabilities	4.9		168.1		255.1		(3.2		)	424.9

Long-term liabilities:
Long-term debt, less current portion	380.0		—		2,012.8		—			2,392.8
Other long-term liabilities	12.9		15.1		31.2		—			59.2

Partners' capital	776.2		1,021.8		141.1		(1,162.9		)	776.2
Interest of non-controlling partners in subsidiaries	4,808.3		—		4,808.3		(4,808.3		)	4,808.3
Total partners' capital	5,584.5		1,021.8		4,949.4		(5,971.2		)	5,584.5
Total liabilities and partners' capital	$	5,982.3	$	1,205.0	$	7,248.5	$	(5,974.4	)	$	8,461.4

Condensed Consolidating Statements of Operations



Condensed Consolidating Statements of Operations
Three Months Ended March 31, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	280.0		$	455.1		$	(3.6	)	$	731.5

Costs of product/services sold	—			246.7			286.6			(3.6		)	529.7
Expenses:
Operations and maintenance	—			15.5			35.1			—			50.6
General and administrative	1.9			1.4			24.2			—			27.5
Depreciation, amortization and accretion	—			9.8			64.4			—			74.2
	1.9			26.7			123.7			—			152.3
Other operating income (expense):
Loss on long-lived assets, net	—			(0.2		)	(0.8		)	—			(1.0		)
Operating income (loss)	(1.9		)	6.4			44.0			—			48.5
Earnings from unconsolidated affiliates, net	—			—			3.4			—			3.4
Interest and debt expense, net	(3.7		)	—			(29.9		)	—			(33.6		)
Other income, net	—			0.2			—			—			0.2
Equity in net income of subsidiary	23.8			—			—			(23.8		)	—
Income (loss) before income taxes	18.2			6.6			17.5			(23.8		)	18.5
Provision for income taxes	0.1			—			0.3			—			0.4
Net income (loss)	18.1			6.6			17.2			(23.8		)	18.1
Net income attributable to non-controlling partners in subsidiaries	—			—			(9.8		)	—			(9.8		)
Net income (loss) attributable to partners	$	18.1		$	6.6		$	7.4		$	(23.8	)	$	8.3



Condensed Consolidating Statements of Operations
Three Months Ended March 31, 2014
(in millions)
	Parent			Guarantor Subsidiaries		Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	437.9	$	537.0		$	(3.3	)	$	971.6

Costs of product/services sold	—			391.2		398.1			(3.3		)	786.0
Expenses:
Operations and maintenance	—			16.1		28.0			—			44.1
General and administrative	2.8			1.0		24.1			—			27.9
Depreciation, amortization and accretion	—			10.7		55.6			—			66.3
	2.8			27.8		107.7			—			138.3
Other operating income (expense):
Gain on long-lived assets, net	—			—		0.5			—			0.5
Loss on contingent consideration	—			—		(2.1		)	—			(2.1		)
Operating income (loss)	(2.8		)	18.9		29.6			—			45.7
Loss from unconsolidated affiliates, net	—			—		(0.1		)	—			(0.1		)
Interest and debt expense, net	(3.6		)	—		(28.1		)	—			(31.7		)
Other income, net	—			0.1		—			—			0.1
Equity in net income of subsidiary	19.6			—		—			(19.6		)	—
Income (loss) before income taxes	13.2			19.0		1.4			(19.6		)	14.0
Provision for income taxes	—			0.1		0.7			—			0.8
Net income (loss)	13.2			18.9		0.7			(19.6		)	13.2
Net loss attributable to non-controlling partners in subsidiary	—			—		6.4			—			6.4
Net income (loss) attributable to partners	$	13.2		$	18.9	$	7.1		$	(19.6	)	$	19.6

Condensed Consolidating Statements of Comprehensive Income



Condensed Consolidating Statements of Comprehensive Income
Three Months Ended March 31, 2015
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Net income (loss)	$	18.1	$	6.6	$	17.2	$	(23.8	)	$	18.1
Change in fair value of Suburban Propane Partners LP units	—		—		—		—			—
Comprehensive income (loss)	$	18.1	$	6.6	$	17.2	$	(23.8	)	$	18.1



Condensed Consolidating Statements of Comprehensive Income
Three Months Ended March 31, 2014
(in millions)
	Parent			Guarantor Subsidiaries		Non- Guarantor Subsidiaries		Eliminations			Consolidated
Net income (loss)	$	13.2		$	18.9	$	0.7	$	(19.6	)	$	13.2
Change in fair value of Suburban Propane Partners LP units	(0.8		)	—		—		—			(0.8		)
Comprehensive income (loss)	$	12.4		$	18.9	$	0.7	$	(19.6	)	$	12.4

Condensed Consolidating Statements of Cash Flows



Condensed Consolidating Statements of Cash Flows
Three Months Ended March 31, 2015
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities:	$	(5.4	)	$	85.0		$	77.0		$	—		$	156.6

Cash flows from investing activities:
Purchases of property, plant and equipment	(0.1		)	(4.0		)	(43.3		)	—			(47.4		)
Investment in unconsolidated affiliates	(0.2		)	—			(17.9		)	—			(18.1		)
Proceeds from sale of assets	—			0.2			0.3			—			0.5
Capital contribution from consolidated affiliates, net	10.5			—			—			(10.5		)	—
Other	(0.2		)	—			—			—			(0.2		)
Net cash provided by (used in) investing activities	10.0			(3.8		)	(60.9		)	(10.5		)	(65.2		)

Cash flows from financing activities:
Proceeds from the issuance of long-term debt	138.1			—			1,114.6			—			1,252.7
Principal payments on long-term debt	(199.9		)	—			(970.0		)	—			(1,169.9		)
Payments on capital leases	—			—			(0.7		)	—			(0.7		)
Payments for debt-related deferred costs	—			—			(11.1		)	—			(11.1		)
Distributions paid to partners	(25.8		)	—			(10.5		)	10.5			(25.8		)
Distributions paid to non-controlling partners	—			—			(74.3		)	—			(74.3		)
Taxes paid for unit-based compensation vesting	—			(1.4		)	(1.7		)	—			(3.1		)
Change in intercompany balances	80.2			(80.2		)	—			—			—
Other	—			(0.1		)	(0.2		)	—			(0.3		)
Net cash provided by (used in) financing activities	(7.4		)	(81.7		)	46.1			10.5			(32.5		)

Net change in cash	(2.8		)	(0.5		)	62.2			—			58.9
Cash at beginning of period	3.7			0.5			4.6			—			8.8
Cash at end of period	$	0.9		$	—		$	66.8		$	—		$	67.7

Business Description (Narrative) (Detail)	3 Months Ended
Business Description (Narrative) (Detail)	Mar. 31, 2015 segment $ / shares shares	May 05, 2015
Business Description [Line Items]
Number of Operating Segments \| segment	3
Crestwood Equity Partners LP
Business Description [Line Items]
General partner ownership percentage	4.00%
Incentive Distribution Rights, Distribution Percentage	100.00%
CMLP
Business Description [Line Items]
Incentive Distribution Rights, Percent	50.00%
Incentive Distribution, Distribution Per Unit \| $ / shares	$ 0.37
Common unit \| First Reserve Management, L.P.
Business Description [Line Items]
General partner ownership percentage	26.00%
Common unit \| Crestwood Equity Partners LP
Business Description [Line Items]
General partner ownership percentage	11.00%
Subordinated unit
Business Description [Line Items]
Units of Partnership Interest, Amount \| shares	4,387,889
Subsequent Event
Business Description [Line Items]
Equity interest issued or issuable, conversion ratio		2.75

Basis of Presentation and Summary of Significant Accounting Policies (Cash Flow Reclassifications) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2014 USD ($)
Accounting Policies [Abstract]
Reimbursements of property, plant and equipment	$ 9.6

Acquisitions (Narrative) (Details) $ in Millions	Mar. 21, 2014 USD ($) double_bottom_body_tanks trailer_tanks tractor bbl	Mar. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)	Jun. 30, 2014 USD ($)	Mar. 31, 2014 USD ($)
Business Acquisition [Line Items]
Goodwill		$ 2,491.8	$ 2,491.8		$ 2,548.6
Red Rock
Business Acquisition [Line Items]
Consideration Transferred	$ 13.8
Payments to Acquire Businesses, Gross	12.1
Deferred Payments	$ 1.8
Trailer Tanks \| trailer_tanks	56
Double Bottom Tanks \| double_bottom_body_tanks	22
Tractors \| tractor	44
Crude Hauling Capacity (barrels per day) \| bbl	28,000
Property, plant and equipment					10.6
Goodwill					3.2
Storage and Transportation
Business Acquisition [Line Items]
Goodwill				$ 726.3	728.6
NGL and Crude Services
Business Acquisition [Line Items]
Goodwill		$ 1,427.2			$ 1,463.2

Certain Balance Sheet Information (Property, Plant And Equipment) (Details) - USD ($) $ in Millions	Mar. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 4,291.7	$ 4,273.9
Less: accumulated depreciation and depletion	414.0	380.1
Property, plant and equipment, net	3,877.7	3,893.8
Capital lease assets	5.5	5.3
Gathering systems and pipelines
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,417.8	1,410.9
Facilities and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,638.0	1,648.3
Buildings, land, rights-of-way, storage contracts and easements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	843.5	841.5
Vehicles
Property, Plant and Equipment [Line Items]
Property, plant and equipment	46.6	45.2
Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment	174.1	156.5
Base gas
Property, Plant and Equipment [Line Items]
Property, plant and equipment	37.5	37.5
Salt deposits
Property, Plant and Equipment [Line Items]
Property, plant and equipment	120.5	120.5
Office furniture and fixtures
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 13.7	$ 13.5

Certain Balance Sheet Information (Intangible Assets) (Details) - USD ($) $ in Millions	Mar. 31, 2015	Dec. 31, 2014
Finite-Lived Intangible Assets [Line Items]
Intangible assets	$ 1,448.9	$ 1,441.9
Less: accumulated amortization	235.4	210.6
Total intangible assets, net	1,213.5	1,231.3
Customer accounts
Finite-Lived Intangible Assets [Line Items]
Intangible assets	583.7	583.7
Covenants not to compete
Finite-Lived Intangible Assets [Line Items]
Intangible assets	9.6	9.6
Gas gathering, compression and processing contracts
Finite-Lived Intangible Assets [Line Items]
Intangible assets	726.1	730.2
Acquired storage contracts
Finite-Lived Intangible Assets [Line Items]
Intangible assets	29.0	29.0
Trademarks
Finite-Lived Intangible Assets [Line Items]
Intangible assets	32.2	32.2
Deferred financing costs
Finite-Lived Intangible Assets [Line Items]
Intangible assets	$ 68.3	$ 57.2

Certain Balance Sheet Information (Accrued Expenses and Other Liabilities) (Details) - USD ($) $ in Millions	Mar. 31, 2015	Dec. 31, 2014
Balance Sheet Related Disclosures [Abstract]
Accrued expenses	$ 36.3	$ 52.5
Accrued property taxes	4.5	2.2
Accrued product purchases payable	0.4	0.7
Tax payable	0.0	1.6
Interest payable	14.5	23.5
Accrued additions to property, plant and equipment	9.1	20.0
Commitments and contingent liabilities (Note 12)	0.0	40.0
Capital leases	1.7	1.9
Deferred revenue	11.3	12.2
Total accrued expenses and other liabilities	$ 77.8	$ 154.6

Investments in Unconsolidated Affiliates (Net Investments In and Earnings (Loss) from Unconsolidated Affiliates) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Investment	$ 316.6		$ 295.1
Earnings (loss) from unconsolidated affiliates, net	$ 3.4	$ (0.1)
Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Ownership Percentage	50.00%
Investment	$ 244.2		232.9
Earnings (loss) from unconsolidated affiliates, net	2.5	0.3
Difference between carrying amount and underlying equity	52.9
Amortization	$ 0.8	0.8
Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Ownership Percentage	50.01%
Investment	$ 42.8		36.0
Earnings (loss) from unconsolidated affiliates, net	0.9	0.0
Difference between carrying amount and underlying equity	30.0
Amortization	$ 0.3
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Ownership Percentage	50.01%
Investment	$ 29.6		$ 26.2
Earnings (loss) from unconsolidated affiliates, net	$ 0.0	$ (0.4)

Investments in Unconsolidated Affiliates Narrative (Details) - USD ($)	1 Months Ended	3 Months Ended
	Apr. 30, 2015	Mar. 31, 2015	Mar. 31, 2014
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments		$ 18,100,000	$ 19,800,000
Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		0	0
Powder River Basin Industrial Complex, LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments		300,000	0
Payments to acquire equity method investments		3,700,000	2,500,000
Crestwood Niobrara LLC \| Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments		8,800,000	$ 17,300,000
Crestwood Niobrara LLC \| Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments		$ 5,900,000
Subsequent Event \| Jackalope Gas Gathering Services, L.L.C.
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments	$ 4,500,000
Subsequent Event \| Tres Palacios Holdings LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from equity method investments	$ 2,100,000

Risk Management (Notional Amounts and Terms of Company's Derivative Financial Instruments) (Details) - bbl bbl in Millions	Mar. 31, 2015	Dec. 31, 2014
Propane Crude And Heating Oil \| Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount	5.9	6.8
Propane Crude And Heating Oil \| Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount	6.8	8.4
Natural Gas \| Fixed Price Payor
Derivative [Line Items]
Derivative, notional amount	0.0	0.2
Natural Gas \| Fixed Price Receiver
Derivative [Line Items]
Derivative, notional amount	0.0	0.1

Risk Management (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Derivative [Line Items]
Collateral posted for commodity derivative instruments	$ 11.8		$ 33.6
Price Risk Contracts \| Maximum
Derivative [Line Items]
Remaining maturity	36 months
Percent of contracts expiring in the next twelve months	94.00%
Commodity contract
Derivative [Line Items]
Gain (loss) on derivative instruments not designated as hedging	$ (2.9)	$ (0.5)
Aggregate fair value of commodity derivative instruments	6.3		5.2
Collateral posted for commodity derivative instruments	0.0		1.8
NYMEX Margin Deposit
Derivative [Line Items]
Aggregate fair value of commodity derivative instruments	21.3		36.9
NYMEX margin deposits	$ 28.9		$ 41.9

Fair Value Measurements (Schedule of Carrying Values and Estimated Fair Values of Senior Notes) (Details) - USD ($) $ in Millions	Mar. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Fair value	$ 10.6	$ 11.6
Crestwood Midstream Partners LP \| Senior Notes
Debt Instrument [Line Items]
Carrying amount	350.9	351.0
Fair value	363.6	360.5
Crestwood Midstream Partners LP \| Nrgm Credit Facility
Debt Instrument [Line Items]
Carrying amount	503.8	504.0
Fair value	500.3	481.6
CEQP Senior Notes \| Senior Notes
Debt Instrument [Line Items]
Carrying amount	10.6	11.4
Senior Notes, 2022 \| Senior Notes
Debt Instrument [Line Items]
Carrying amount	600.0
Senior Notes, 2022 \| Crestwood Midstream Partners LP \| Crestwood Midstream Senior Notes
Debt Instrument [Line Items]
Fair value	607.5	568.5
Senior Notes, 2023 \| Crestwood Midstream Partners LP \| Crestwood Midstream Senior Notes
Debt Instrument [Line Items]
Fair value	710.5	0.0
Crestwood Midstream Partners LP \| Senior Notes, 2022 \| Senior Notes
Debt Instrument [Line Items]
Carrying amount	600.0	600.0
Crestwood Midstream Partners LP \| Senior Notes, 2023 \| Crestwood Midstream Senior Notes
Debt Instrument [Line Items]
Carrying amount	700.0	0.0
Crestwood Midstream Partners LP \| Senior Notes, 2023 \| Senior Notes
Debt Instrument [Line Items]
Carrying amount	$ 700.0	$ 0.0

Fair Value Measurements (Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	Mar. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	$ 41.1	$ 147.2
Assets from price risk management, total	29.5	79.8
SPH units	6.1	6.1
Assets, Fair Value Disclosure, Excluding Netting Adjustments	47.2	153.3
Netting agreements	(11.6)	(67.4)
Total assets at fair value	35.6	85.9
Liabilities from price risk management	35.4	100.8
Liabilities from price risk management, total	8.6	25.4
Interest rate swaps	1.3	1.6
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	36.7	102.4
Netting agreements	(26.8)	(75.4)
Total liabilities at fair value	9.9	27.0
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	0.0	0.5
SPH units	6.1	6.1
Assets, Fair Value Disclosure, Excluding Netting Adjustments	6.1	6.6
Liabilities from price risk management	0.2	1.6
Interest rate swaps	0.0	0.0
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	0.2	1.6
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	41.1	146.7
SPH units	0.0	0.0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	41.1	146.7
Liabilities from price risk management	35.2	99.2
Interest rate swaps	1.3	1.6
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	36.5	100.8
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	0.0	0.0
SPH units	0.0	0.0
Assets, Fair Value Disclosure, Excluding Netting Adjustments	0.0	0.0
Liabilities from price risk management	0.0	0.0
Interest rate swaps	0.0	0.0
Liabilities, Fair Value Disclosure, Excluding Netting Adjustments	$ 0.0	$ 0.0

Long-Term Debt (Components Of Long-Term Debt) (Details) - USD ($) $ in Millions	Mar. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Total debt	$ 2,479.1	$ 2,396.5
Less: current portion	36.3	3.7
Total long-term debt	2,442.8	2,392.8
Senior Notes \| CEQP Senior Notes
Debt Instrument [Line Items]
Senior notes	10.6	11.4
Senior Notes \| Senior Notes, 2019
Debt Instrument [Line Items]
Senior notes	350.0
Senior Notes \| Senior Notes, 2019 \| Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Senior notes	350.0	350.0
Senior Notes \| Senior Notes, 2020
Debt Instrument [Line Items]
Senior notes	500.0
Senior Notes \| Senior Notes, 2020 \| Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Senior notes	500.0	500.0
Senior Notes \| Senior Notes, 2022
Debt Instrument [Line Items]
Senior notes	600.0
Senior Notes \| Senior Notes, 2022 \| Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Senior notes	600.0	600.0
Senior Notes \| Senior Notes, 2023 \| Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Senior notes	700.0	0.0
Premium on Crestwood Midstream 2019 Senior Notes \| Senior Notes, 2019 \| Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Premium on senior notes	0.9	1.0
Fair value adjustment of Crestwood Midstream 2020 Senior Notes \| Senior Notes, 2020 \| Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Fair value adjustment	3.8	4.0
Other
Debt Instrument [Line Items]
Other	5.8	6.1
Revolving Credit Facility \| Crestwood Midstream Revolver \| Crestwood Midstream Partners LP
Debt Instrument [Line Items]
Credit agreement outstanding carrying value	0.0	555.0
Revolving Credit Facility \| Line of Credit \| CEQP Credit Facility
Debt Instrument [Line Items]
Credit agreement outstanding carrying value	$ 308.0	$ 369.0

Long-Term Debt (Narrative) (Detail)			3 Months Ended
Long-Term Debt (Narrative) (Detail)	Apr. 08, 2015 USD ($)	Dec. 03, 2014	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015 USD ($) swap	Mar. 31, 2014 USD ($)	Feb. 28, 2015 USD ($) swap	Dec. 31, 2014 USD ($)
Debt Instrument [Line Items]
Repayments of Long-term Debt					$ 1,169,900,000	$ 372,600,000
Debt Instrument, Interest Rate, Stated Percentage					7.00%
Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage					6.25%
Revolving Credit Facility \| Line of Credit
Debt Instrument [Line Items]
Credit agreement outstanding carrying value					$ 1,000,000,000
Line of Credit Facility, Expiration Period					5 years
CEQP Credit Facility
Debt Instrument [Line Items]
Total Funded Debt to Consolidated Ebitda					3.25
Consolidated Ebitda To Consolidated Interest Expense					7.91
Fixed rate, range low end							0.84%
Fixed rate, range high end					2.52%		2.35%
CEQP Credit Facility \| Credit Agreement
Debt Instrument [Line Items]
Interest Coverage Ratio Minimum					2.50
CEQP Credit Facility \| Interest Rate Swap
Debt Instrument [Line Items]
Number of Interest Rate Derivatives Held \| swap					1		5
Aggregate notional amount, cash flow hedges					$ 50,000,000		$ 175,000,000
Gain (Loss) on Hedging Activity					300,000
CEQP Credit Facility \| Revolving Credit Facility \| Credit Agreement
Debt Instrument [Line Items]
Credit Agreement amount available					134,300,000
Letters of credit outstanding					$ 52,700,000			$ 56,700,000
CEQP Credit Facility \| Revolving Credit Facility \| Minimum \| LIBO Rate
Debt Instrument [Line Items]
Line of Credit Facility, Interest Rate at Period End					2.43%
Long-term Debt, Weighted Average Interest Rate					2.43%			3.02%
CEQP Credit Facility \| Revolving Credit Facility \| Maximum \| LIBO Rate
Debt Instrument [Line Items]
Line of Credit Facility, Interest Rate at Period End					4.50%
CEQP Credit Facility \| Revolving Credit Facility \| Line of Credit \| Amended and Restated
Debt Instrument [Line Items]
Credit agreement outstanding carrying value					$ 495,000,000
Consolidated Leverage Ratio Maximum					5.25
CEQP Credit Facility \| Revolving Credit Facility \| Line of Credit \| Forecast \| Amended and Restated
Debt Instrument [Line Items]
Consolidated Leverage Ratio Maximum			4.75	5.00
Crestwood Midstream Revolver \| Revolving Credit Facility
Debt Instrument [Line Items]
Letters of credit outstanding					$ 5,600,000			$ 15,100,000
Debt Instrument, Unused Borrowing Capacity, Amount					$ 429,100,000
Total Funded Debt to Consolidated Ebitda					4.58
Consolidated Ebitda To Consolidated Interest Expense					4.15
Debt, Weighted Average Interest Rate								2.86%
Consolidated Leverage Ratio Maximum					5.00
Consolidated Leverage Ratio, Maximum, Post Acquisitions		5.50			5.50
Interest Coverage Ratio Minimum					2.50
Crestwood Midstream Revolver \| Revolving Credit Facility \| Minimum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate								2.66%
Crestwood Midstream Revolver \| Revolving Credit Facility \| Maximum
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate								4.75%
Crestwood Midstream Revolver \| Swing Line Loans
Debt Instrument [Line Items]
Credit agreement outstanding carrying value					$ 25,000,000
Crestwood Midstream Revolver \| Standby Letters of Credit
Debt Instrument [Line Items]
Credit agreement outstanding carrying value					250,000,000
Senior Notes, 2019 \| Senior Notes
Debt Instrument [Line Items]
Senior notes					$ 350,000,000
Debt Instrument, Interest Rate, Stated Percentage					7.75%
Senior Notes, 2020 \| Senior Notes
Debt Instrument [Line Items]
Senior notes					$ 500,000,000
Debt Instrument, Interest Rate, Stated Percentage					6.00%
Senior Notes, 2022 \| Senior Notes
Debt Instrument [Line Items]
Senior notes					$ 600,000,000
Debt Instrument, Interest Rate, Stated Percentage					6.125%
Senior Notes, 2023 \| Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage					6.25%
Crestwood Midstream Partners LP \| Senior Notes, 2019 \| Senior Notes
Debt Instrument [Line Items]
Senior notes					$ 350,000,000			$ 350,000,000
Crestwood Midstream Partners LP \| Senior Notes, 2020 \| Senior Notes
Debt Instrument [Line Items]
Senior notes					500,000,000			500,000,000
Crestwood Midstream Partners LP \| Senior Notes, 2022 \| Senior Notes
Debt Instrument [Line Items]
Senior notes					600,000,000			600,000,000
Crestwood Midstream Partners LP \| Senior Notes, 2023 \| Senior Notes
Debt Instrument [Line Items]
Long-term Debt					700,000,000
Senior notes					700,000,000			0
Proceeds from Issuance of Debt					$ 688,900,000
Tres Palacios Holdings LLC
Debt Instrument [Line Items]
Ownership Percentage					50.01%
Crestwood Midstream Partners LP \| Senior Notes
Debt Instrument [Line Items]
Senior notes					$ 350,900,000			$ 351,000,000
Crestwood Midstream Partners LP \| Tres Palacios Holdings LLC
Debt Instrument [Line Items]
Ownership Percentage					50.01%
Subsequent Event \| Crestwood Midstream Revolver \| Revolving Credit Facility \| Line of Credit
Debt Instrument [Line Items]
Proceeds from Issuance of Debt	$ 315,000,000
Subsequent Event \| Senior Notes, 2019 \| Senior Notes
Debt Instrument [Line Items]
Early Repayment of Senior Debt	364,100,000
Interest Paid	500,000
Call Premium On Debt Redemption	$ 13,600,000

Earnings Per Limited Partner Unit (Details) - shares	3 Months Ended
Earnings Per Limited Partner Unit (Details) - shares	Mar. 31, 2015	Mar. 31, 2014
Legacy Crestwood
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Units excluded from dilutive earnings per share	0	0

Partners' Capital (Narrative) (Details) - USD ($)					1 Months Ended	3 Months Ended
Partners' Capital (Narrative) (Details) - USD ($)	Apr. 23, 2015	Feb. 13, 2015	Jul. 10, 2014	Jun. 17, 2014	Aug. 31, 2012	Mar. 31, 2015	Mar. 31, 2014
Distribution Made to Limited Partner [Line Items]
Offering Costs, Partnership Interests			$ 0.020
Incentive Distribution, Distribution						$ 25,800,000	$ 25,600,000
Net Income (Loss) Attributable to Noncontrolling Interest						$ 9,800,000	(6,400,000)
Distribution Made to Limited Partner, Unit Distribution		414,325
Partners' Capital Account, Sale of Units			$ 300,000,000
Preferred Partner
Distribution Made to Limited Partner [Line Items]
Partners' Capital, Contingent Distribution Amount Per Share						$ 0.7059
Partner's Capital, Unpaid Distribution, Accrual Percentage				2.8125%
Partners' Capital, Distribution Amount Per Share						$ 0.5804
CMLP
Distribution Made to Limited Partner [Line Items]
Net Income (Loss) Attributable to Noncontrolling Interest						$ (5,000,000)	(9,500,000)
Crestwood Niobrara LLC
Distribution Made to Limited Partner [Line Items]
Net Income (Loss) Attributable to Noncontrolling Interest						5,600,000	3,100,000
Suburban Propane Partners L P
Distribution Made to Limited Partner [Line Items]
Limited Liability Company L L C Or Limited Partnership L P Members Or Limited Partners Ownership Interest Shares					142,000
Non-Controlling Partners
Distribution Made to Limited Partner [Line Items]
Proceeds from Noncontrolling Interests, Additional Capital Contributions							12,300,000
Cash Distribution
Distribution Made to Limited Partner [Line Items]
Limited Partners' Capital Account, Distribution Amount						$ 74,300,000	$ 74,100,000
Preferred Units, Class D \| Crestwood Niobrara LLC
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Unit Distribution						3,680,570	2,210,294
Preferred Units, Class A
Distribution Made to Limited Partner [Line Items]
Partners' Capital Account, Private Placement of Units, Price Per Unit				$ 25.10
Maximum \| Class A Purchasers \| Preferred Units, Class A
Distribution Made to Limited Partner [Line Items]
Partners' Capital Account, Sale of Units				$ 500,000,000
Subsequent Event
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Unit Distribution	423,903
Subsequent Event \| Cash Distribution
Distribution Made to Limited Partner [Line Items]
Distribution Made to Member or Limited Partner, Distributions Declared, Per Unit	$ 0.1375

Partners' Capital (Schedule of Partners' Capital Account, Distriubtions) (Details) - USD ($) $ / shares in Units, $ in Millions	Feb. 13, 2015	Feb. 06, 2015	Feb. 14, 2014	Feb. 07, 2014
Statement of Partners' Capital [Abstract]
Distribution Made to Member or Limited Partner, Date of Record		Feb. 06, 2015		Feb. 07, 2014
Distribution Made to Member or Limited Partner, Distribution Date	Feb. 13, 2015		Feb. 14, 2014
Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit	$ 0.1375		$ 0.1375
Distribution Made to Limited Partner, Cash Distributions Paid	$ 25.8		$ 25.6

Partners' Capital (Components of Net Income (Loss) Attributable to Non-Controlling Interests) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Distribution Made to Limited Partner [Line Items]
Net Income (Loss) Attributable to Noncontrolling Interest	$ 9.8	$ (6.4)
CMLP
Distribution Made to Limited Partner [Line Items]
Net Income (Loss) Attributable to Noncontrolling Interest	(5.0)	(9.5)
Crestwood Niobrara LLC
Distribution Made to Limited Partner [Line Items]
Net Income (Loss) Attributable to Noncontrolling Interest	5.6	3.1
Preferred Units, Class A \| CMLP
Distribution Made to Limited Partner [Line Items]
Net Income (Loss) Attributable to Noncontrolling Interest	$ 9.2	$ 0.0

Equity Plans (Restricted Unit Activity) (Details)	3 Months Ended
Equity Plans (Restricted Unit Activity) (Details)	Mar. 31, 2015 $ / shares shares
Restricted Stock Units (RSUs) \| Crestwood LTIP
Units
Unvested - January 1, 2015 \| shares	1,315,880
Vested - restricted units \| shares	(743,252)
Granted - restricted units \| shares	1,157,174
Forfeited(1) \| shares	(69,122)
Unvested - March 31, 2015 \| shares	2,023,552
Weighted-Average Grant Date Fair Value
Unvested - January 1, 2015 \| $ / shares	$ 13.21
Vested - restricted units \| $ / shares	12.96
Granted - restricted units \| $ / shares	6.80
Forfeited(1) \| $ / shares	10.52
Unvested - March 31, 2015 \| $ / shares	$ 8.56
Restricted Stock Units (RSUs) \| Crestwood Midstream LTIP
Units
Unvested - January 1, 2015 \| shares	834,796
Vested - restricted units \| shares	(424,653)
Granted - restricted units \| shares	512,404
Forfeited(1) \| shares	(37,997)
Unvested - March 31, 2015 \| shares	1,045,589
Weighted-Average Grant Date Fair Value
Unvested - January 1, 2015 \| $ / shares	$ 23.18
Vested - restricted units \| $ / shares	23.11
Granted - restricted units \| $ / shares	16.01
Forfeited(1) \| $ / shares	20.93
Unvested - March 31, 2015 \| $ / shares	$ 18.68
Phantom Share Units (PSUs) \| Crestwood LTIP
Units
Granted - restricted units \| shares	362,872
Weighted-Average Grant Date Fair Value
Granted - restricted units \| $ / shares	$ 6.72
Phantom Share Units (PSUs) \| Crestwood Midstream LTIP
Units
Granted - restricted units \| shares	161,039
Weighted-Average Grant Date Fair Value
Granted - restricted units \| $ / shares	$ 16.02

Equity Plans (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
Equity Plans (Narrative) (Details) - USD ($) $ in Millions	Apr. 30, 2015	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total Compensation Cost Not yet Recognized, Period for Recognition		3 years
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Percent		10.00%
Defined Contribution Plan, Maximum Purchasable Units		200,000
Defined Contribution Plan, Employer Matching Contribution, Percent of Match		10.00%
Unit Purchase Plan, Shares Purchased Under Plan		2,011
Crestwood LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation		$ 2.8	$ 2.5
Shares Paid for Tax Withholding for Share Based Compensation		242,365	47,800
Crestwood LTIP \| Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period		69,122
Total Compensation Cost Not yet Recognized		$ 14.1		$ 8.1
Grants in Period, Fair Value		$ 7.9
Common Stock, Capital Shares Reserved for Future Issuance		12,713,653
Crestwood LTIP \| Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants in Period, Fair Value		$ 2.4
Crestwood LTIP \| CMLP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense			$ 1.7
Crestwood Midstream LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation		$ 3.0	$ 2.9
Shares Paid for Tax Withholding for Share Based Compensation		134,591	7,456
Crestwood Midstream LTIP \| Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period		37,997
Grants in Period, Fair Value		$ 8.2
Common Stock, Capital Shares Reserved for Future Issuance		17,199,153
Crestwood Midstream LTIP \| Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants in Period, Fair Value		$ 2.6
Crestwood Midstream LTIP \| CMLP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share Based Compensation Expense Allocated to Subsidiary		2.2
Crestwood Midstream LTIP \| CMLP \| Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total Compensation Cost Not yet Recognized		$ 15.7		$ 9.5
Employee Severance \| Crestwood LTIP \| Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period		36,542
Employee Severance \| Crestwood Midstream LTIP \| Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period		21,583
Subsequent Event
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unit Purchase Plan, Shares Purchased Under Plan	3,841

Commitments and Contingencies (Details) $ in Millions	1 Months Ended	12 Months Ended
Commitments and Contingencies (Details) $ in Millions	Mar. 31, 2014 defendant	Dec. 31, 2014 USD ($) shares	Mar. 31, 2015 USD ($)	Feb. 28, 2015 USD ($)	Nov. 08, 2013 bbl people
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Self Insurance Reserve		$ 14.6	$ 12.8
Self Insurance Reserve Expected To Be Paid Subsequent To Next Fiscal Year			9.7
Escrow Deposit of Common Units \| shares		3,309,797
Loss Contingency Accrual, at Carrying Value			1.0
Antero
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Contingent Consideration, Liability, Current			$ 40.0	$ 40.0
Arrow Acquisition Class Action Lawsuit
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Loss Contingency, Loss of Life, Number \| people					47
Loss Contingency, Number of Defendants \| defendant	53
Minimum \| Arrow Acquisition Class Action Lawsuit
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Barrels of Oil Equivalents Spilled \| bbl					50,000

Commitments and Contingencies Environmental Compliance (Details) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2015 USD ($)	Dec. 31, 2014 USD ($) bbl Release	May 06, 2015 bbl
Site Contingency [Line Items]
Accrual for Environmental Loss Contingencies		$ 1.1
Fort Berthold Indian Reservation
Site Contingency [Line Items]
Site Contingency, Loss Exposure, Number of Releases of Produced Water \| Release		3
Site Contingency, Loss Exposure, Release of Produced Water \| bbl		28,000
Accrual for Environmental Loss Contingencies	$ 0.3
Site Contingency, Loss Exposure in Excess of Accrual, Low Estimate	0.3
Site Contingency, Loss Exposure in Excess of Accrual, High Estimate	$ 0.8
Subsequent Event \| Fort Berthold Indian Reservation
Site Contingency [Line Items]
Site Contingency, Loss Exposure, Release of Produced Water \| bbl			8,000

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Related Party Transaction [Line Items]
Related party receivables	$ 1.2		$ 0.6
Gathering and processing revenues	1.0	$ 0.9
Reimbursement of operations and maintenance expenses	0.9	0.0
Related Party Transaction, Due from (to) Related Party [Abstract]
Accounts payable	5.2		5.6
Affiliated Entity
Related Party Transaction [Line Items]
Related party receivables	1.2		0.6
Gathering and processing revenues	1.0	0.9
Gathering and processing costs of product/services sold(1)	8.3	11.0
Reimbursement of general and administrative expenses	0.1	$ 0.1
Related Party Transaction, Due from (to) Related Party [Abstract]
Accounts payable	$ 5.2		$ 5.6

Segments (Reconciliation of Net Income (Loss) to EBITDA) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Segment Reporting [Abstract]
Net income	$ 18.1	$ 13.2
Interest and debt expense, net	33.6	31.7
Provision for income taxes	(0.4)	(0.8)
Depreciation, amortization and accretion	(74.2)	(66.3)
EBITDA	$ 126.3	$ 112.0

Segments (Summary Of Segment Information) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2015 USD ($) segment	Mar. 31, 2014 USD ($)	Dec. 31, 2014 USD ($)	Jun. 30, 2014 USD ($)
Number of Operating Segments \| segment	3
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	$ 731.5	$ 971.6
Cost of Goods and Services Sold	529.7	786.0
Operations and maintenance	50.6	44.1
General and administrative	27.5	27.9
Gain (loss) on long-lived assets, net	(1.0)	0.5
Loss on contingent consideration	0.0	(2.1)
Loss on contingent consideration	0.0	(2.1)
Earnings (loss) from unconsolidated affiliates, net	3.4	(0.1)
Other income, net	0.2	0.1
EBITDA	126.3	112.0
Goodwill	2,491.8	2,548.6	$ 2,491.8
Total assets	8,348.2	8,480.5	$ 8,461.4
Cash expenditures for property, plant and equipment	47.4	82.4
Gathering and Processing Operations
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	78.5	79.5
Cost of Goods and Services Sold	12.7	18.7
Operations and maintenance	14.9	13.4
General and administrative	0.0	0.0
Gain (loss) on long-lived assets, net	(0.3)	0.5
Loss on contingent consideration		(2.1)
Earnings (loss) from unconsolidated affiliates, net	2.5	0.3
Other income, net	0.0	0.0
EBITDA	53.1	46.1
Goodwill	338.3	356.8
Total assets	2,617.1	2,547.8
Cash expenditures for property, plant and equipment	11.4	46.3
Storage and Transportation
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	45.7	51.0
Cost of Goods and Services Sold	3.3	6.8
Operations and maintenance	4.3	6.2
General and administrative	0.0	0.0
Gain (loss) on long-lived assets, net	(0.7)	0.0
Loss on contingent consideration		0.0
Earnings (loss) from unconsolidated affiliates, net	0.9	0.0
Other income, net	0.0	0.0
EBITDA	38.3	38.0
Goodwill		728.6		$ 726.3
Total assets	1,976.1	2,162.7
Cash expenditures for property, plant and equipment	2.7	1.6
NGL and Crude Services
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	607.5	841.1
Cost of Goods and Services Sold	513.9	760.5
Operations and maintenance	31.4	24.5
General and administrative	0.0	0.0
Gain (loss) on long-lived assets, net	0.0	0.0
Loss on contingent consideration		0.0
Earnings (loss) from unconsolidated affiliates, net	0.0	(0.4)
Other income, net	0.0	0.0
EBITDA	62.2	55.7
Goodwill	1,427.2	1,463.2
Total assets	3,570.3	3,582.1
Cash expenditures for property, plant and equipment	33.1	30.9
Intersegment
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	(0.2)	0.0
Cost of Goods and Services Sold	(0.2)	0.0
Operations and maintenance	0.0	0.0
General and administrative	0.0	0.0
Gain (loss) on long-lived assets, net	0.0	0.0
Loss on contingent consideration		0.0
Earnings (loss) from unconsolidated affiliates, net	0.0	0.0
Other income, net		0.0
EBITDA	0.0	0.0
Goodwill	0.0	0.0
Total assets	0.0	0.0
Cash expenditures for property, plant and equipment	0.0	0.0
Corporate Assets [Member]
Segment Reporting Information, Additional Information [Abstract]
Loss on contingent consideration		0.0
Corporate
Segment Reporting Information, Additional Information [Abstract]
Operating revenues	0.0	0.0
Cost of Goods and Services Sold	0.0	0.0
Operations and maintenance	0.0	0.0
General and administrative	27.5	27.9
Gain (loss) on long-lived assets, net	0.0	0.0
Earnings (loss) from unconsolidated affiliates, net	0.0	0.0
Other income, net	0.2	0.1
EBITDA	(27.3)	(27.8)
Goodwill	0.0	0.0
Total assets	184.7	187.9
Cash expenditures for property, plant and equipment	$ 0.2	$ 3.6

Condensed Consolidating Financial Information Narrative (Details)	3 Months Ended
	Mar. 31, 2015
CEQP Finance Corp. [Member]
Condensed Financial Statements, Captions [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	100.00%

Condensed Consolidating Financial Information (Statement of Operations Adjustments to Prior Periods) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Condensed Financial Statements, Captions [Line Items]
General and administrative	$ 27.5	$ 27.9
Operating Income (Loss)	48.5	45.7
Equity in net income of subsidiary	0.0	0.0
Income (loss) before income taxes	18.5	14.0
Net income	18.1	13.2
Net income attributable to Crestwood Equity Partners LP	8.3	19.6
Parent Company
Condensed Financial Statements, Captions [Line Items]
General and administrative	1.9	2.8
Operating Income (Loss)	(1.9)	(2.8)
Equity in net income of subsidiary	23.8	19.6
Income (loss) before income taxes	18.2	13.2
Net income	18.1	13.2
Net income attributable to Crestwood Equity Partners LP	18.1	13.2
Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
General and administrative	1.4	1.0
Operating Income (Loss)	6.4	18.9
Equity in net income of subsidiary	0.0	0.0
Income (loss) before income taxes	6.6	19.0
Net income	6.6	18.9
Net income attributable to Crestwood Equity Partners LP	6.6	18.9
Consolidation, Eliminations
Condensed Financial Statements, Captions [Line Items]
General and administrative	0.0	0.0
Operating Income (Loss)	0.0	0.0
Equity in net income of subsidiary	(23.8)	(19.6)
Income (loss) before income taxes	(23.8)	(19.6)
Net income	(23.8)	(19.6)
Net income attributable to Crestwood Equity Partners LP	$ (23.8)	(19.6)
Scenario, Previously Reported \| Parent Company
Condensed Financial Statements, Captions [Line Items]
General and administrative		0.0
Operating Income (Loss)		0.0
Equity in net income of subsidiary		16.8
Income (loss) before income taxes		13.2
Net income		13.2
Net income attributable to Crestwood Equity Partners LP		13.2
Scenario, Previously Reported \| Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
General and administrative		3.8
Operating Income (Loss)		16.1
Equity in net income of subsidiary		0.0
Income (loss) before income taxes		16.2
Net income		16.1
Net income attributable to Crestwood Equity Partners LP		16.1
Scenario, Previously Reported \| Consolidation, Eliminations
Condensed Financial Statements, Captions [Line Items]
General and administrative		0.0
Operating Income (Loss)		0.0
Equity in net income of subsidiary		(16.8)
Income (loss) before income taxes		(16.8)
Net income		(16.8)
Net income attributable to Crestwood Equity Partners LP		$ (16.8)

Condensed Consolidating Financial Information (Cash Flow Adjustments to Prior Periods) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	$ 156.6	$ 81.9
Purchases of property, plant and equipment	(47.4)	(82.4)
Capital contributions from consolidated affiliates and other	0.0	0.0
Net cash used in investing activities	(65.2)	(114.3)
Proceeds from the issuance of long-term debt	1,252.7	496.4
Principal payments on long-term debt	(1,169.9)	(372.6)
Distributions to partners	(25.8)	(25.6)
Change in intercompany balances	0.0	0.0
Net cash provided by (used in) financing activities	(32.5)	34.9
Consolidation, Eliminations
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	0.0	0.0
Purchases of property, plant and equipment	0.0	0.0
Capital contributions from consolidated affiliates and other	(10.5)	(10.5)
Net cash used in investing activities	(10.5)	(10.5)
Proceeds from the issuance of long-term debt	0.0	0.0
Principal payments on long-term debt	0.0	0.0
Distributions to partners	10.5	10.5
Change in intercompany balances	0.0	0.0
Net cash provided by (used in) financing activities	10.5	10.5
Parent Company
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	(5.4)	(6.9)
Purchases of property, plant and equipment	(0.1)	(2.7)
Capital contributions from consolidated affiliates and other	10.5	10.5
Net cash used in investing activities	10.0	7.8
Proceeds from the issuance of long-term debt	138.1	190.4
Principal payments on long-term debt	(199.9)	(183.8)
Distributions to partners	(25.8)	(25.6)
Change in intercompany balances	80.2	18.1
Net cash provided by (used in) financing activities	(7.4)	(0.9)
Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	85.0	21.1
Purchases of property, plant and equipment	(4.0)	(2.4)
Capital contributions from consolidated affiliates and other	0.0	0.0
Net cash used in investing activities	(3.8)	(2.4)
Proceeds from the issuance of long-term debt	0.0	0.0
Principal payments on long-term debt	0.0	0.0
Distributions to partners	0.0	0.0
Change in intercompany balances	(80.2)	(18.1)
Net cash provided by (used in) financing activities	$ (81.7)	(18.5)
Scenario, Previously Reported \| Consolidation, Eliminations
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities		0.0
Purchases of property, plant and equipment		0.0
Capital contributions from consolidated affiliates and other		(46.6)
Net cash used in investing activities		(46.6)
Proceeds from the issuance of long-term debt		0.0
Principal payments on long-term debt		0.0
Distributions to partners		46.6
Change in intercompany balances		0.0
Net cash provided by (used in) financing activities		46.6
Scenario, Previously Reported \| Parent Company
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities		0.0
Purchases of property, plant and equipment		0.0
Capital contributions from consolidated affiliates and other		36.1
Net cash used in investing activities		36.1
Proceeds from the issuance of long-term debt		0.0
Principal payments on long-term debt		0.0
Distributions to partners		(36.1)
Change in intercompany balances		0.0
Net cash provided by (used in) financing activities		(36.1)
Scenario, Previously Reported \| Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities		14.2
Purchases of property, plant and equipment		(5.1)
Capital contributions from consolidated affiliates and other		10.5
Net cash used in investing activities		5.4
Proceeds from the issuance of long-term debt		190.4
Principal payments on long-term debt		(183.8)
Distributions to partners		(25.6)
Change in intercompany balances		0.0
Net cash provided by (used in) financing activities		$ (19.4)

Condensed Consolidating Financial Information (Condensed Consolidating Balance Sheet) (Details) - USD ($) $ in Millions	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Limited Partners' Capital Account	$ 758.0	$ 776.2
Current assets:
Cash	67.7	8.8	$ 7.7	$ 5.2	$ 5.2
Other Receivables	288.6	379.0
Accounts receivable	289.8	379.6
Related party receivables	1.2	0.6
Accounts Receivable, Intercompany, Current	0.0	0.0
Inventory	23.9	46.6
Other current assets	57.4	103.1
Total current assets	438.8	538.1
Property, plant and equipment, net	3,877.7	3,893.8
Goodwill and intangible assets, net	3,705.3	3,723.1
Investment in consolidated affiliates	0.0	0.0
Investment in unconsolidated affiliates (Note 5)	316.6	295.1
Other assets	9.8	11.3
Total assets	8,348.2	8,461.4	8,480.5
Current liabilities:
Accounts payable	213.5	235.6
Accounts payable - related party	5.2	5.6
Accounts payable - intercompany	0.0	0.0
Total accounts payable	218.7	241.2
Other current liabilities	122.7	183.7
Total current liabilities	341.4	424.9
Long-term liabilities:
Long-term debt, less current portion (Note 8)	2,442.8	2,392.8
Other long-term liabilities	59.1	59.2
Interest of non-controlling partners in subsidiaries	4,746.9	4,808.3
Total partners’ capital	5,504.9	5,584.5
Total liabilities and partners’ capital	8,348.2	8,461.4
Parent Company
Limited Partners' Capital Account	758.0	776.2
Current assets:
Cash	0.9	3.7	0.1	0.1
Other Receivables	0.0	0.0
Accounts receivable	2.8	3.2
Related party receivables	0.0	0.0
Accounts Receivable, Intercompany, Current	2.8	3.2
Inventory	0.0	0.0
Other current assets	0.0	0.0
Total current assets	3.7	6.9
Property, plant and equipment, net	2.9	2.5
Goodwill and intangible assets, net	1.4	1.7
Investment in consolidated affiliates	5,829.5	5,971.2
Investment in unconsolidated affiliates (Note 5)	0.0	0.0
Other assets	0.0	0.0
Total assets	5,837.5	5,982.3
Current liabilities:
Accounts payable	0.0	0.0
Accounts payable - related party	0.0	0.0
Accounts payable - intercompany	0.0	0.0
Total accounts payable	0.0	0.0
Other current liabilities	0.0	4.9
Total current liabilities	0.0	4.9
Long-term liabilities:
Long-term debt, less current portion (Note 8)	321.1	380.0
Other long-term liabilities	11.5	12.9
Interest of non-controlling partners in subsidiaries	4,746.9	4,808.3
Total partners’ capital	5,504.9	5,584.5
Total liabilities and partners’ capital	5,837.5	5,982.3
Guarantor Subsidiaries
Limited Partners' Capital Account	944.2	1,021.8
Current assets:
Cash	0.0	0.5	2.6	2.4
Other Receivables	97.1	137.5
Accounts receivable	97.2	137.8
Related party receivables	0.1	0.3
Accounts Receivable, Intercompany, Current	0.0	0.0
Inventory	14.7	38.6
Other current assets	33.8	84.4
Total current assets	145.7	261.3
Property, plant and equipment, net	225.3	227.1
Goodwill and intangible assets, net	703.2	706.7
Investment in consolidated affiliates	0.0	0.0
Investment in unconsolidated affiliates (Note 5)	0.0	0.0
Other assets	8.6	9.9
Total assets	1,082.8	1,205.0
Current liabilities:
Accounts payable	90.4	109.5
Accounts payable - related party	2.5	2.5
Accounts payable - intercompany	0.0	0.0
Total accounts payable	92.9	112.0
Other current liabilities	29.6	56.1
Total current liabilities	122.5	168.1
Long-term liabilities:
Long-term debt, less current portion (Note 8)	0.0	0.0
Other long-term liabilities	16.1	15.1
Interest of non-controlling partners in subsidiaries	0.0	0.0
Total partners’ capital	944.2	1,021.8
Total liabilities and partners’ capital	1,082.8	1,205.0
Non-Guarantor Subsidiaries
Limited Partners' Capital Account	138.4	141.1
Current assets:
Cash	66.8	4.6	5.0	2.7
Other Receivables	191.5	241.5
Accounts receivable	192.6	241.8
Related party receivables	1.1	0.3
Accounts Receivable, Intercompany, Current	0.0	0.0
Inventory	9.2	8.0
Other current assets	23.6	18.7
Total current assets	292.2	273.1
Property, plant and equipment, net	3,649.5	3,664.2
Goodwill and intangible assets, net	3,000.7	3,014.7
Investment in consolidated affiliates	0.0	0.0
Investment in unconsolidated affiliates (Note 5)	316.6	295.1
Other assets	1.2	1.4
Total assets	7,260.2	7,248.5
Current liabilities:
Accounts payable	123.1	126.1
Accounts payable - related party	2.7	3.1
Accounts payable - intercompany	2.8	3.2
Total accounts payable	128.6	132.4
Other current liabilities	93.1	122.7
Total current liabilities	221.7	255.1
Long-term liabilities:
Long-term debt, less current portion (Note 8)	2,121.7	2,012.8
Other long-term liabilities	31.5	31.2
Interest of non-controlling partners in subsidiaries	4,746.9	4,808.3
Total partners’ capital	4,885.3	4,949.4
Total liabilities and partners’ capital	7,260.2	7,248.5
Consolidation, Eliminations
Limited Partners' Capital Account	(1,082.6)	(1,162.9)
Current assets:
Cash	0.0	0.0	$ 0.0	$ 0.0
Other Receivables	0.0	0.0
Accounts receivable	(2.8)	(3.2)
Related party receivables	0.0	0.0
Accounts Receivable, Intercompany, Current	(2.8)	(3.2)
Inventory	0.0	0.0
Other current assets	0.0	0.0
Total current assets	(2.8)	(3.2)
Property, plant and equipment, net	0.0	0.0
Goodwill and intangible assets, net	0.0	0.0
Investment in consolidated affiliates	(5,829.5)	(5,971.2)
Investment in unconsolidated affiliates (Note 5)	0.0	0.0
Other assets	0.0	0.0
Total assets	(5,832.3)	(5,974.4)
Current liabilities:
Accounts payable	0.0	0.0
Accounts payable - related party	0.0	0.0
Accounts payable - intercompany	(2.8)	(3.2)
Total accounts payable	(2.8)	(3.2)
Other current liabilities	0.0	0.0
Total current liabilities	(2.8)	(3.2)
Long-term liabilities:
Long-term debt, less current portion (Note 8)	0.0	0.0
Other long-term liabilities	0.0	0.0
Interest of non-controlling partners in subsidiaries	(4,746.9)	(4,808.3)
Total partners’ capital	(5,829.5)	(5,971.2)
Total liabilities and partners’ capital	$ (5,832.3)	$ (5,974.4)

Condensed Consolidating Financial Information (Condensed Consolidating Statements Of Operations) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Revenue	$ 731.5	$ 971.6
Cost of product/services sold	529.7	786.0
Expenses:
Operations and maintenance	50.6	44.1
General and administrative	27.5	27.9
Depreciation, amortization and accretion	74.2	66.3
Other income, net	0.2	0.1
Costs and Expenses	152.3	138.3
Gain (Loss) on Disposition of Assets	(1.0)	0.5
Loss on contingent consideration	0.0	(2.1)
Operating income	48.5	45.7
Earnings (loss) from unconsolidated affiliates, net	3.4	(0.1)
Other income (expense):
Interest and debt expense, net	(33.6)	(31.7)
Other income, net	0.2	0.1
Equity in net income of subsidiary	0.0	0.0
Income before income taxes	18.5	14.0
Provision for income taxes	0.4	0.8
Net income	18.1	13.2
Net income attributable to non-controlling partners in subsidiary	(9.8)	6.4
Net income attributable to Crestwood Equity Partners LP	8.3	19.6
Parent Company
Revenue	0.0	0.0
Cost of product/services sold	0.0	0.0
Expenses:
Operations and maintenance	0.0	0.0
General and administrative	1.9	2.8
Depreciation, amortization and accretion	0.0	0.0
Costs and Expenses	1.9	2.8
Gain (Loss) on Disposition of Assets	0.0	0.0
Loss on contingent consideration		0.0
Operating income	(1.9)	(2.8)
Earnings (loss) from unconsolidated affiliates, net	0.0	0.0
Other income (expense):
Interest and debt expense, net	(3.7)	(3.6)
Other income, net	0.0	0.0
Equity in net income of subsidiary	23.8	19.6
Income before income taxes	18.2	13.2
Provision for income taxes	0.1	0.0
Net income	18.1	13.2
Net income attributable to non-controlling partners in subsidiary	0.0	0.0
Net income attributable to Crestwood Equity Partners LP	18.1	13.2
Guarantor Subsidiaries
Revenue	280.0	437.9
Cost of product/services sold	246.7	391.2
Expenses:
Operations and maintenance	15.5	16.1
General and administrative	1.4	1.0
Depreciation, amortization and accretion	9.8	10.7
Costs and Expenses	26.7	27.8
Gain (Loss) on Disposition of Assets	(0.2)	0.0
Loss on contingent consideration		0.0
Operating income	6.4	18.9
Earnings (loss) from unconsolidated affiliates, net	0.0	0.0
Other income (expense):
Interest and debt expense, net	0.0	0.0
Other income, net	0.2	0.1
Equity in net income of subsidiary	0.0	0.0
Income before income taxes	6.6	19.0
Provision for income taxes	0.0	0.1
Net income	6.6	18.9
Net income attributable to non-controlling partners in subsidiary	0.0	0.0
Net income attributable to Crestwood Equity Partners LP	6.6	18.9
Non-Guarantor Subsidiaries
Revenue	455.1	537.0
Cost of product/services sold	286.6	398.1
Expenses:
Operations and maintenance	35.1	28.0
General and administrative	24.2	24.1
Depreciation, amortization and accretion	64.4	55.6
Costs and Expenses	123.7	107.7
Gain (Loss) on Disposition of Assets	(0.8)	0.5
Loss on contingent consideration		(2.1)
Operating income	44.0	29.6
Earnings (loss) from unconsolidated affiliates, net	3.4	(0.1)
Other income (expense):
Interest and debt expense, net	(29.9)	(28.1)
Other income, net	0.0	0.0
Equity in net income of subsidiary	0.0	0.0
Income before income taxes	17.5	1.4
Provision for income taxes	0.3	0.7
Net income	17.2	0.7
Net income attributable to non-controlling partners in subsidiary	(9.8)	6.4
Net income attributable to Crestwood Equity Partners LP	7.4	7.1
Consolidation, Eliminations
Revenue	(3.6)	(3.3)
Cost of product/services sold	(3.6)	(3.3)
Expenses:
Operations and maintenance	0.0	0.0
General and administrative	0.0	0.0
Depreciation, amortization and accretion	0.0	0.0
Costs and Expenses	0.0	0.0
Gain (Loss) on Disposition of Assets	0.0	0.0
Loss on contingent consideration		0.0
Operating income	0.0	0.0
Earnings (loss) from unconsolidated affiliates, net	0.0	0.0
Other income (expense):
Interest and debt expense, net	0.0	0.0
Other income, net	0.0	0.0
Equity in net income of subsidiary	(23.8)	(19.6)
Income before income taxes	(23.8)	(19.6)
Provision for income taxes	0.0	0.0
Net income	(23.8)	(19.6)
Net income attributable to non-controlling partners in subsidiary	0.0	0.0
Net income attributable to Crestwood Equity Partners LP	$ (23.8)	$ (19.6)

Condensed Consolidating Financial Information (Condensed Consolidating Statements of Comprehensive Income) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Net income	$ 18.1	$ 13.2
Change in fair value of Suburban Propane Partners, L.P. units (Note 10)	0.0	(0.8)
Comprehensive income	18.1	12.4
Parent Company
Condensed Financial Statements, Captions [Line Items]
Net income	18.1	13.2
Change in fair value of Suburban Propane Partners, L.P. units (Note 10)	0.0	(0.8)
Comprehensive income	18.1	12.4
Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net income	6.6	18.9
Change in fair value of Suburban Propane Partners, L.P. units (Note 10)	0.0	0.0
Comprehensive income	6.6	18.9
Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net income	17.2	0.7
Change in fair value of Suburban Propane Partners, L.P. units (Note 10)	0.0	0.0
Comprehensive income	17.2	0.7
Consolidation, Eliminations
Condensed Financial Statements, Captions [Line Items]
Net income	(23.8)	(19.6)
Change in fair value of Suburban Propane Partners, L.P. units (Note 10)	0.0	0.0
Comprehensive income	$ (23.8)	$ (19.6)

Condensed Consolidating Financial Information (Condensed Consolidating Statements Of Cash Flows) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Cash flows from operating activities	$ 156.6	$ 81.9
Cash flows from investing activities:
Acquisitions, net of cash acquired	0.0	(12.1)
Purchases of property, plant and equipment	(47.4)	(82.4)
Investment in unconsolidated affiliates	(18.1)	(19.8)
Proceeds from sale of assets	0.5	0.0
Capital contributions from consolidated affiliates and other	0.0	0.0
Other	(0.2)	0.0
Net cash used in investing activities	(65.2)	(114.3)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	1,252.7	496.4
Principal payments on long-term debt	(1,169.9)	(372.6)
Payments on capital leases	(0.7)	(1.1)
Payments for debt-related deferred costs	(11.1)	0.0
Distributions to partners	(25.8)	(25.6)
Distributions paid to non-controlling partners	(74.3)	(74.1)
Net proceeds from issuance of preferred equity of subsidiary	0.0	12.3
Other	(0.3)	0.0
Payments For Other Financing Activities		(1.5)
Net cash provided by (used in) financing activities	(32.5)	34.9
Net change in cash	58.9	2.5
Cash at beginning of period	8.8	5.2
Cash at end of period	67.7	7.7
Taxes paid for unit-based compensation vesting	(3.1)	(0.4)
Change in intercompany balances	0.0	0.0
Parent Company
Cash flows from operating activities	(5.4)	(6.9)
Cash flows from investing activities:
Acquisitions, net of cash acquired		0.0
Purchases of property, plant and equipment	(0.1)	(2.7)
Investment in unconsolidated affiliates	(0.2)	0.0
Proceeds from sale of assets	0.0
Capital contributions from consolidated affiliates and other	10.5	10.5
Other	(0.2)
Net cash used in investing activities	10.0	7.8
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	138.1	190.4
Principal payments on long-term debt	(199.9)	(183.8)
Payments on capital leases	0.0
Payments for debt-related deferred costs	0.0
Distributions to partners	(25.8)	(25.6)
Distributions paid to non-controlling partners	0.0	0.0
Net proceeds from issuance of preferred equity of subsidiary		0.0
Other	0.0
Payments For Other Financing Activities		0.0
Net cash provided by (used in) financing activities	(7.4)	(0.9)
Net change in cash	(2.8)	0.0
Cash at beginning of period	3.7	0.1
Cash at end of period	0.9	0.1
Taxes paid for unit-based compensation vesting	0.0
Change in intercompany balances	80.2	18.1
Guarantor Subsidiaries
Cash flows from operating activities	85.0	21.1
Cash flows from investing activities:
Acquisitions, net of cash acquired		0.0
Purchases of property, plant and equipment	(4.0)	(2.4)
Investment in unconsolidated affiliates	0.0	0.0
Proceeds from sale of assets	0.2
Capital contributions from consolidated affiliates and other	0.0	0.0
Other	0.0
Net cash used in investing activities	(3.8)	(2.4)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	0.0	0.0
Principal payments on long-term debt	0.0	0.0
Payments on capital leases	0.0
Payments for debt-related deferred costs	0.0
Distributions to partners	0.0	0.0
Distributions paid to non-controlling partners	0.0	0.0
Net proceeds from issuance of preferred equity of subsidiary		0.0
Other	(0.1)
Payments For Other Financing Activities		(0.4)
Net cash provided by (used in) financing activities	(81.7)	(18.5)
Net change in cash	(0.5)	0.2
Cash at beginning of period	0.5	2.4
Cash at end of period	0.0	2.6
Taxes paid for unit-based compensation vesting	(1.4)
Change in intercompany balances	(80.2)	(18.1)
Non-Guarantor Subsidiaries
Cash flows from operating activities	77.0	67.7
Cash flows from investing activities:
Acquisitions, net of cash acquired		(12.1)
Purchases of property, plant and equipment	(43.3)	(77.3)
Investment in unconsolidated affiliates	(17.9)	(19.8)
Proceeds from sale of assets	0.3
Capital contributions from consolidated affiliates and other	0.0	0.0
Other	0.0
Net cash used in investing activities	(60.9)	(109.2)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	1,114.6	306.0
Principal payments on long-term debt	(970.0)	(188.8)
Payments on capital leases	(0.7)
Payments for debt-related deferred costs	(11.1)
Distributions to partners	(10.5)	(10.5)
Distributions paid to non-controlling partners	(74.3)	(74.1)
Net proceeds from issuance of preferred equity of subsidiary		12.3
Other	(0.2)
Payments For Other Financing Activities		(1.1)
Net cash provided by (used in) financing activities	46.1	43.8
Net change in cash	62.2	2.3
Cash at beginning of period	4.6	2.7
Cash at end of period	66.8	5.0
Taxes paid for unit-based compensation vesting	(1.7)
Change in intercompany balances	0.0	0.0
Consolidation, Eliminations
Cash flows from operating activities	0.0	0.0
Cash flows from investing activities:
Acquisitions, net of cash acquired		0.0
Purchases of property, plant and equipment	0.0	0.0
Investment in unconsolidated affiliates	0.0	0.0
Proceeds from sale of assets	0.0
Capital contributions from consolidated affiliates and other	(10.5)	(10.5)
Other	0.0
Net cash used in investing activities	(10.5)	(10.5)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	0.0	0.0
Principal payments on long-term debt	0.0	0.0
Payments on capital leases	0.0
Payments for debt-related deferred costs	0.0
Distributions to partners	10.5	10.5
Distributions paid to non-controlling partners	0.0	0.0
Net proceeds from issuance of preferred equity of subsidiary		0.0
Other	0.0
Payments For Other Financing Activities		0.0
Net cash provided by (used in) financing activities	10.5	10.5
Net change in cash	0.0	0.0
Cash at beginning of period	0.0	0.0
Cash at end of period	0.0	0.0
Taxes paid for unit-based compensation vesting	0.0
Change in intercompany balances	$ 0.0	$ 0.0