Crosstex Energy Inactive 10-K28 Feb 142013 FY Annual reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
Document and Entity Information (USD $)	Dec. 31, 2013	Feb. 14, 2014	Jun. 30, 2013
Document And Entity Information [Abstract]	'	'	'
Document Type	'10-K	'	'
Document Fiscal Period Focus	'FY	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Amendment Flag	'false	'	'
Entity Registrant Name	'CROSSTEX ENERGY INC	'	'
Entity Central Index Key	'0001209821	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Accelerated Filer	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Common Stock, Shares Outstanding	'	48,021,537	'
Entity Public Float	'	'	$651,728,568
Share Price	'	'	$19.76

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Current assets:	'	'
Cash and cash equivalents	$1,821	$2,976
Accounts receivable:	'	'
Trade, net of allowance for bad debts of $629 and $535 respectively	74,196	63,690
Accrued revenues	208,597	150,734
Imbalances	4,235	1,533
Other	6,670	3,561
Fair value of derivative assets	302	3,234
Natural gas and natural gas liquids inventory, prepaid expenses and other	17,935	11,866
Assets held for disposition	0	22,599
Total current assets	313,756	260,193
Property and Equipment:	'	'
Transmission assets	769,424	397,381
Gathering systems	729,179	723,626
Gas processing plants	614,435	586,294
Other property and equipment	131,333	88,326
Construction in process	297,348	180,976
Total property and equipment	2,541,719	1,976,603
Accumulated depreciation	-603,936	-504,442
Total property and equipment, net	1,937,783	1,472,161
Intangible assets, net of accumulated amortization of $227,883 and $263,305, respectively	316,222	425,005
Goodwill	153,802	152,627
Fair Value of derivative assets	556	0
Investment in limited liability company	103,673	90,500
Other assets, net	23,035	25,989
Total assets	2,848,827	2,426,475
Current liabilities:	'	'
Drafts payable	13,413	4,093
Accounts payable	18,140	25,839
Accrued gas, condensate and crude oil purchases	200,585	140,344
Accrued imbalances payable	4,832	2,333
Accrued Capital Expenditures	31,270	23,495
Fair value of derivative liabilities	1,168	1,310
Accrued interest	26,915	26,712
Liabilities held for disposition	0	3,572
Other Liabilities, Current	41,256	'
Other current liabilities	'	48,421
Total current liabilities	337,579	276,119
Long-term debt	1,200,472	1,036,305
Other long-term liabilities	27,077	30,256
Deferred Tax Liability	129,428	133,555
Fair value of derivatives liabilities	755	0
Stockholders' equity:	'	'
Common Stock (150,000,000 shares authorized, $.01 par value, 47,756,973 and 47,413,789 issued and outstanding in 2013 and 2012, respectively)	476	473
Additional Paid in Capital	307,835	274,635
Accumulated Deficit	-171,263	-117,583
Accumulated other comprehensive income (loss)	-58	141
Total Crosstex Energy, Inc. stockholders' equity	136,990	157,666
Interest of non-controlling partners in the Partnership	1,016,526	792,574
Total stockholders' equity	1,153,516	950,240
Total liabilities and stockholders' equity	$2,848,827	$2,426,475

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Statement of Financial Position [Abstract]	'	'
Allowance for trade and other receivables	$629	$535
Accumulated amortization of intangible assets	$227,883	$263,305
Common Stock, Shares Authorized	150,000,000	150,000,000
Common Stock, Shares, Issued	47,756,973	47,413,789
Common Stock, Par or Stated Value Per Share	$0.01	$0.01

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Revenues:	'	'	'
Midstream	$1,944,312	$1,791,288	$2,013,942
Operating costs and expenses:	'	'	'
Purchased gas, condensate, NGLs and crude oil	1,546,987	1,397,530	1,638,777
Operating expenses	150,858	130,882	111,778
General and administrative	79,993	65,083	55,516
(Gain) loss on sale of property	-1,055	-342	264
Loss on derivatives	2,304	1,006	7,776
Impairments	72,576	0	0
Depreciation and amortization	140,285	162,300	125,358
Total operating costs and expenses	1,991,948	1,756,459	1,939,469
Operating income (loss)	-47,636	34,829	74,473
Other income (expense):	'	'	'
Interest expense, net of interest income	-76,859	-86,515	-79,227
Equity in income of limited liability company	46	3,250	0
Other income	1,600	5,054	707
Total other expense	-75,213	-78,211	-78,520
Loss before non-controlling interest and income taxes	-122,849	-43,382	-4,047
Income Tax Benefit	10,214	6,642	2,768
Net loss	-112,635	-36,740	-1,279
Less: Net income (loss) attributable to the noncontrolling interest	-82,999	-24,259	4,728
Net loss attributable to Crosstex Energy, Inc.	($29,636)	($12,481)	($6,007)
Net loss per common Share:	'	'	'
Earnings Per Share, Basic	($0.60)	($0.26)	($0.12)
Earnings Per Share, Diluted	($0.60)	($0.26)	($0.12)
Weighted Average Number of Shares Outstanding, Basic	47,664	47,384	47,150
Weighted Average Number of Shares Outstanding, Diluted	47,664	47,384	47,150
Dividend paid per common share	$0.49	$0.47	$0.37

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Statement of Comprehensive Income [Abstract]	'	'	'
Other Comprehensive Income (Loss), Reclassification Adjustment on Derivatives Included in Net Income, Tax (Deprecated 2013-01-31)	($69)	($48)	$195
Net loss	-112,635	-36,740	-1,279
Hedging (gains) losses reclassified to earnings, net of taxes of $(69), $(48) and $195, respectively	-1,002	-641	1,769
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	-234	1,642	-1,446
Comprehensive loss	-113,871	-35,739	-956
Comprehensive income (loss) attributable to non-controlling interest	-84,096	-23,484	4,991
Comprehensive loss attributable to Crosstex Energy, Inc.	-29,775	-12,255	-5,947
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax	($49)	$181	($159)

Consolidated_Statements_of_Cha

Consolidated Statements of Changes in Stockholders' Equity (USD $)	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interest [Member]
In Thousands, except Share data	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interest [Member]
Balance, at Dec. 31, 2010	$901,478	$468	$242,390	($58,298)	($145)	$717,063
Balance, Shares at Dec. 31, 2010	'	46,894,000	'	'	'	'
Conversion of restricted stock for common, net of shares withheld for taxes, value	1,068	3	1,071	0	0	0
Conversion of restricted stock for common, net of shares withheld for taxes, Shares	'	300,000	'	'	'	'
Change in equity due to issuance of units by the Partnership	-476	0	-476	0	0	0
Stock-based Compensation	7,556	0	3,368	0	0	4,188
Common dividends	-17,872	0	0	-17,872	0	0
Net loss	-1,279	0	0	-6,007	0	4,728
Hedging gains or losses reclassified to earnings	1,769	0	0	0	330	1,439
Adjustment in fair value of derivatives	-1,446	0	0	0	-270	-1,176
Non Controlling Partners Impact Of Conversion Of Restricted Units and Option Exercises	-1,206	0	0	0	0	-1,206
Distribution to non-controlling interest	-58,209	0	0	0	0	-58,209
Balance, at Dec. 31, 2011	829,247	471	244,211	-82,177	-85	666,827
Balance, Shares at Dec. 31, 2011	'	47,194,000	'	'	'	'
Issuance of units by the Partnership to non-controlling interest, Shares	'	0	'	'	'	'
Issuance of units by the Partnership to non-controlling interest, Value	232,791	0	0	0	0	232,791
Conversion of restricted stock for common, net of shares withheld for taxes, value	794	2	796	0	0	0
Conversion of restricted stock for common, net of shares withheld for taxes, Shares	'	220,000	'	'	'	'
Change in equity due to issuance of units by the Partnership	8,610	0	24,500	0	0	-15,890
Stock-based Compensation	9,483	0	4,481	0	0	5,002
Common dividends	-22,925	0	0	-22,925	0	0
Net loss	-36,740	0	0	-12,481	0	-24,259
Hedging gains or losses reclassified to earnings	-641	0	0	0	-81	-560
Adjustment in fair value of derivatives	1,642	0	0	0	307	1,335
Non Controlling Partners Impact Of Conversion Of Restricted Units and Option Exercises	-594	0	0	0	0	-594
Distribution to non-controlling interest	-69,839	0	0	0	0	-69,839
Purchase of non-controlling interest	0	0	2,239	0	0	-2,239
Balance, at Dec. 31, 2012	950,240	473	274,635	-117,583	141	792,574
Balance, Shares at Dec. 31, 2012	'	47,414,000	'	'	'	'
Issuance of units by the Partnership to non-controlling interest, Shares	'	0	'	'	'	'
Issuance of units by the Partnership to non-controlling interest, Value	419,498	0	0	0	0	419,498
Conversion of restricted stock for common, net of shares withheld for taxes, value	2,087	3	2,090	0	0	0
Conversion of restricted stock for common, net of shares withheld for taxes, Shares	'	321,000	'	'	'	'
Change in equity due to issuance of units by the Partnership	-7,224	0	27,959	0	-60	-35,123
Stock-based Compensation	14,383	0	7,185	0	0	7,198
Common dividends	-24,044	0	0	-24,044	0	'
Net loss	-112,635	0	0	-29,636	0	-82,999
Hedging gains or losses reclassified to earnings	-1,002	0	0	0	-116	-886
Adjustment in fair value of derivatives	-234	0	0	0	-23	-211
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period	'	22,000	'	'	'	'
Partners' Capital Account, Option Exercise	146	0	146	0	0	0
Non Controlling Partners Impact Of Conversion Of Restricted Units and Option Exercises	-1,093	0	0	0	0	-1,093
Distribution to non-controlling interest	-91,497	0	0	0	0	-91,497
Contribution from non-controlling interest in subsidiary	9,065	0	0	0	0	9,065
Balance, at Dec. 31, 2013	$1,153,516	$476	$307,835	($171,263)	($58)	$1,016,526
Balance, Shares at Dec. 31, 2013	'	47,757,000	'	'	'	'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash Flows from Operating Activities	'	'	'
Net loss	($112,635)	($36,740)	($1,279)
Adjustments to Reconcile Net Income (Loss) to Cash Provided by (Used in) Operating Activities [Abstract]	'	'	'
Depreciation and amortization	140,285	162,300	125,358
Impairments	72,576	0	0
Non-cash stock-based compensation	14,383	9,483	7,556
(Gain) loss on sale of property and other assets	-1,055	-3,328	264
Deferred tax (benefit) expense	-18,003	-8,384	-4,540
Loss on derivatives recognized in net loss	2,304	1,006	7,776
Cash Settlements On Derivative Financial Instruments	633	4,514	7,015
Interest paid-in-kind	1,766	0	0
Amortization of debt issue costs	6,457	5,377	6,462
Amortization of discount on notes	1,897	1,897	1,897
Distributions of earnings from limited liability company	3,296	0	0
Equity in income of limited liability company	-46	-3,250	0
Changes in Assets and Liabilities	'	'	'
Accounts receivable, accrued revenue and other	-75,359	-39,120	44,121
Natural gas and natural gas liquids, prepaid expenses and other	-2,880	-4,015	-1,507
Accounts payable, accrued gas and crude oil purchases and other accrued liabilities	55,486	19,744	-37,800
Net cash provided by operating activities	87,839	100,456	141,293
Cash Flows from Investing Activities	'	'	'
Additions to property and equipment	-560,784	-234,849	-97,572
Acquisitions of business	0	-214,957	0
Proceeds from sale of property	19,420	11,773	478
Investment in limited liability company	-30,594	-52,250	-35,000
Distribution from limited liability company in excess of earnings	14,172	0	0
Net cash provided by (used in) investing activities	-557,786	-490,283	-132,094
Cash Flows from Financing Activities	'	'	'
Proceeds from borrowings	558,126	806,500	471,250
Payments on borrowings	-397,622	-570,500	-393,308
Payments on capital lease obligations	-3,266	-3,112	-3,122
Increase (decrease) in drafts payable	9,320	-1,912	5,854
Debt refinancing costs	-3,508	-7,155	-3,954
Distributions to non-controlling interest in the Partnership	-91,497	-69,839	-58,209
Contribution from Noncontrolling Interests	4,819	0	0
Common dividends paid	-24,044	-22,925	-17,872
Conversion of restricted units, net of units withheld for taxes	-1,928	-1,030	-1,798
Conversion of restricted stock, net of shares withheld for taxes	-2,087	-794	-1,068
Proceeds from exercise of share options	146	0	0
Proceeds from issuance of partnership units	419,498	232,791	0
Proceeds from exercise of partnerhip unit options	835	436	591
Net cash provided by (used in) financing activities	468,792	362,460	-1,636
Net increase (decrease) in cash and cash equivalents	-1,155	-27,367	7,563
Cash and cash equivalents, beginning of period	2,976	30,343	22,780
Cash and cash equivalents, end of period	1,821	2,976	30,343
Cash paid for interest	89,438	81,237	71,950
Cash paid for income taxes	$8,628	$1,706	$1,104

Organization_and_Summary_of_Si

Organization and Summary of Significant Agreement	12 Months Ended
Organization and Summary of Significant Agreement	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization and Summary of Significant Agreements	'
	(1) Organization and Summary of Significant Agreements
	(a) Description of Business
	Crosstex Energy, Inc., a Delaware corporation formed on April 28, 2000, is engaged, through its subsidiaries, in providing midstream energy services, including gathering, processing, transmission and marketing, to producers of natural gas, natural gas liquids ("NGLs"), condensate and crude oil. The Company also provides crude oil, condensate and brine services to producers. The Company connects the wells of natural gas producers in its market areas to its gathering systems, processes natural gas for the removal of NGLs, fractionates NGLs into purity products and markets those products for a fee, transports natural gas and ultimately provides natural gas to a variety of markets. The Company purchases natural gas from natural gas producers and other supply sources and sells that natural gas to utilities, industrial consumers, other marketers and pipelines. The Company operates processing plants that process gas transported to the plants by major interstate pipelines or from its own gathering systems under a variety of fee arrangements. The Company provides a variety of crude services throughout the Ohio River Valley ("ORV") which include crude oil and condensate gathering via pipelines, rail and barge terminal services and trucks and oilfield brine disposal. The Company also has crude oil terminal facilities in south Louisiana that provide access for crude oil producers to the premium markets in this area. The Company's gas gathering systems consist of networks of pipelines that collect natural gas from points near producing wells and transport it to larger pipelines for further transmission. The Company's transmission pipelines primarily receive natural gas from its gathering systems and from third party gathering and transmission systems and deliver natural gas to industrial end-users, utilities and other pipelines. The Company's oil gathering and transmission systems consist of trucking facilities and pipelines that, in exchange for a fee, transport oil from a producer site to an end user. The Company's processing plants remove NGLs and CO2 from a natural gas stream and its fractionators separate the NGLs into separate NGL products, including ethane, propane, iso-butane, normal butane and natural gasoline.
	(b) Organization
	On July 12, 2002, the Company formed Crosstex Energy, L.P. (herein referred to as the Partnership or CELP), a Delaware limited partnership. Crosstex Energy GP, LLC, a wholly owned subsidiary of the Company, is the general partner of the Partnership. As of December 31, 2013, the Company owned 16,414,830 common units in the Partnership through its wholly owned subsidiary, which represented approximately 15.0% of the limited partner interests in the Partnership, and an approximate 1.5% general partner interest. On September 13, 2012, the board of directors of the general partner amended the partnership agreement to convert the general partner's obligation to make capital contributions to the Partnership to maintain its 2% interest in connection with the issuance of additional limited interests by the Partnership to an option of the general partner to make future capital contributions to maintain its then current general partner percentage interest.
	(c) Basis of Presentation
	The accompanying consolidated financial statements include the assets, liabilities and results of operations of the Company and its wholly-owned subsidiaries, including the Partnership. The Partnership proportionately consolidates its undivided 50% interest in a gas processing plant located in the Permian Basin and its undivided 64.29% interest in a gas plant located in south Louisiana. The Company also consolidates its joint venture in E2 as discussed more fully in Note 2. The Company also consolidated its joint venture in Crosstex DC Gathering, J.V. ("CDC"), until it acquired the remaining interest for $0.4 million. The consolidated operations are hereafter referred to collectively as the "Company." All material intercompany balances and transactions have been eliminated.

Significant_Accounting_Policie

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Significant Accounting Policies	'
	(2) Significant Accounting Policies
	(a) Management's Use of Estimates
	The preparation of financial statements in accordance with accounting principles generally accepted in the United States of America requires management of the Company to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the period. Actual results could differ from these estimates.
	(b) Cash and Cash Equivalents
	The Company considers all highly liquid investments with an original maturity of three months or less to be cash equivalents.
	(c) Natural Gas, Natural Gas Liquids, Crude Oil and Condensate Inventory
	Inventories of products consist of natural gas, NGLs, crude oil and condensate. The Company reports these assets at the lower of cost or market.
	(d) Property, Plant, and Equipment
	Property, plant and equipment consist of intrastate gas transmission systems, gas gathering systems, NGL, condensate and crude oil pipelines, natural gas processing plants, NGL fractionation plants and brine disposal wells. Gas required to maintain pipeline minimum pressures is capitalized and classified as property, plant and equipment. Other property and equipment is primarily comprised of the ORV trucking fleet, computer software and equipment, furniture, fixtures, leasehold improvements and office equipment. Property, plant and equipment are recorded at cost. Repairs and maintenance are charged against income when incurred. Renewals and betterments, which extend the useful life of the properties, are capitalized. Interest costs are capitalized to property, plant and equipment during the period the assets are undergoing preparation for intended use. Interest costs totaling $24.5 million, $4.0 million and $0.9 million were capitalized for the years ended December 31, 2013, 2012 and 2011, respectively.
	Depreciation is calculated using the straight-line method based on the estimated useful life of each asset, as follows:


			Useful Lives
	Transmission assets		20 - 30 years
	Gathering systems		15 - 20 years
	Gas processing plants		20 years
	Other property and equipment		3 - 15 years
	Depreciation expense of $99.8 million, $98.2 million and $77.8 million was recorded for the years ended December 31, 2013, 2012 and 2011, respectively. Depreciation expense also includes the amortization of assets classified as capital lease assets.
	Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") 360-10-05-4 requires long-lived assets to be reviewed whenever events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. In order to determine whether an impairment has occurred, the Company compares the net book value of the asset to the undiscounted expected future net cash flows. If an impairment has occurred, the amount of such impairment is determined based on the expected future net cash flows discounted using a rate commensurate with the risk associated with the asset.
	When determining whether impairment of one of our long-lived assets has occurred, we must estimate the undiscounted cash flows attributable to the asset. The Company's estimate of cash flows is based on assumptions regarding the purchase and resale margins on natural gas, condensate and crude oil, volume of available gas, condensate and crude oil available to the asset, markets available to the asset, operating expenses, and future natural gas prices and NGL product prices. The volume of availability of gas to an asset is sometimes based on assumptions regarding future drilling activity, which may be dependent in part on natural gas and crude oil prices. Projections of gas volumes and future commodity prices are inherently subjective and contingent upon a number of variable factors. Any significant variance in any of the above assumptions or factors could materially affect our cash flows, which could require us to record an impairment of an asset.
	(e) Goodwill and Intangible Assets
	Goodwill is the cost of an acquisition less the fair value of the net identifiable assets of the acquired business. The Partnership evaluates goodwill for impairment annually as of July 1, 2013, and whenever events or changes in circumstances indicate it is more likely than not that the fair value of a reporting unit is less than its carrying amount. The Partnership first assesses qualitative factors to evaluate whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as the basis for determining whether it is necessary to perform the two-step goodwill impairment test. The Partnership may elect to perform the two-step goodwill impairment test without completing a qualitative assessment. If a two-step process goodwill impairment test is elected or required, the first step involves comparing the fair value of the reporting unit, to which goodwill has been allocated, with its carrying amount. If the carrying amount of a reporting unit exceeds its fair value, the second step of the process involves comparing the implied fair value to the carrying value of the goodwill for that reporting unit. If the carrying value of the goodwill of a reporting unit exceeds the implied fair value of that goodwill, the excess of the carrying value over the implied fair value is recognized as an impairment loss.
	The Partnership has approximately $153.8 million and $152.6 million of goodwill at December 31, 2013 and 2012, respectively, related to the acquisition of Clearfield Energy, Inc. and its wholly-owned subsidiaries (collectively, "Clearfield") in July 2012. The goodwill recognized from the Clearfield acquisition results primarily from the value of opportunity created from the strategic asset positioning in the Utica and Marcellus shale plays which provides the Partnership with a substantial growth platform in a new geographic area. The goodwill is allocated to the ORV segment. There were no impairment charges resulting from the Partnership's July 1, 2013 impairment testing, and no event indicating impairment has occurred subsequent to that date.
	Intangible assets consist of customer relationships and the value of the dedicated and non-dedicated acreage attributable to pipeline, gathering and processing systems. Intangible assets associated with customer relationships are amortized on a straight-line basis over the expected period of benefits of the customer relationships, which range from three to twenty years. The intangible assets associated with dedicated and non-dedicated acreage attributable to pipeline, gathering and processing systems are being amortized using the units of throughput method of amortization.
	The following table represents the Partnership's total purchased intangible assets at years ended December 31, 2013 and 2012 (in thousands)


			Gross			Accumulated				Net
			Carrying			Amortization				Carrying
			Amount							Amount
	2013
	Customer relationships (1)		$	148,456		$	(65,125	)		$	83,331

	Dedicated and non-dedicated acreage		395,649			(162,758		)		232,891

	Total		$	544,105		$	(227,883	)		$	316,222

	2012
	Customer relationships		$	292,658		$	(130,458	)		$	162,200

	Dedicated and non-dedicated acreage		395,652			(132,847		)		262,805

	Total		$	688,310		$	(263,305	)		$	425,005

	(1) See Note 4-"Acquisition, Disposition and Impairments" for information related to an impairment on the Partnership's Eunice customer relationships in 2013.

	The weighted average amortization period for intangible assets is 19.0 years. Amortization expense for intangibles was approximately $40.5 million, $64.1 million and $47.5 million for the years ended December 31, 2013 , 2012 and 2011, respectively.
	The following table summarizes the Partnership's estimated aggregate amortization expense for the next five years (in thousands):


	2014	$	35,827

	2015	34,430

	2016	32,944

	2017	32,269

	2018	31,882

	Thereafter	148,870

	Total	$	316,222

(f) Investment in Limited Liability Company
On June 22, 2011, the Partnership entered into a limited liability agreement with Howard Energy Partners ("HEP") for an initial capital contribution of $35.0 million in exchange for an individual ownership interest in HEP. In 2013 and 2012, the Partnership made additional capital contributions of $30.6 million and $52.3 million, respectively. Additionally, the Partnership received a distributions of $17.5 million in 2013. HEP owns midstream assets and provides midstream services to Eagle Ford Shale producers. The Partnership owns 30.6 percent of HEP and accounts for this investment under the equity method of accounting. In December 2013, Alinda Capital Partners acquired a 59% capital interest in HEP from Quanta Capital Solutions and GE Energy Financial Services. This investment is reflected on the balance sheet as "Investment in limited liability company." The Partnership's proportional share of earnings is recorded as an increase to this investment account and recorded as equity in income of limited liability company.
(g) Investment in E2

In March 2013, the Company entered into an agreement to form E2 Energy Services, LLC and E2 Appalachian Compression, LLC ("E2"), which are companies that provide compression and stabilization services for producers in the liquids-rich window of the Utica Shale play. The Company owns approximately 93.7% of E2 Energy Services, LLC and a 92.5% interest in E2 Appalachian Compression, LLC and has pre-determined rights to purchase the management ownership interests of E2 in the future. The Company owns a majority interest in E2 and consolidates its investment in E2 pursuant to Financial Accounting Standards Board ("FASB") ASC 810-10-05-08. The Company has committed to invest of approximately $76.0 million in E2 to fund the construction of three new natural gas compression and condensate stabilization facilities, which E2 will own and operate. The facilities are located in Noble and Monroe counties in the southern portion of the Utica Shale play in Ohio. As of December 31, 2013, the Company has invested $60.7 million in E2. Commercial operations of the first facility began during the first quarter of 2014 and the remaining plants are expected to be operational during the first half of 2014.
(h) Other Assets
Unamortized debt issuance costs totaling $22.8 million and $26.0 million as of December 31, 2013 and 2012, respectively, are included in other assets, net. Debt issuance costs are amortized into interest expense using the straight-line method over the term of the debt.
(i) Gas Imbalance Accounting
Quantities of natural gas and NGLs over-delivered or under-delivered related to imbalance agreements are recorded monthly as receivables or payables using weighted average prices at the time of the imbalance. These imbalances are typically settled with deliveries of natural gas or NGLs. The Company had imbalance payables of $4.8 million and $2.3 million at December 31, 2013 and 2012, respectively, which approximate the fair value of these imbalances. The Company had imbalance receivables of $4.2 million and $1.5 million at December 31, 2013 and 2012, respectively, which are carried at the lower of cost or market value.
(j) Asset Retirement Obligations
FASB ASC 410-20-25-16 was issued in March 2005 and became effective at December 31, 2005. FASB ASC 410-20-25-16 clarifies that the term "conditional asset retirement obligation" as used in FASB ASC 410-20, refers to a legal obligation to perform an asset retirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity. Since the obligation to perform the asset retirement activity is unconditional, FASB ASC 410-20-25-16 provides that a liability for the fair value of a conditional asset retirement activity should be recognized if that fair value can be reasonably estimated, even though uncertainty exists about the timing and/or method of settlement. FASB ASC 410-20-25-16 also clarifies when an entity would have sufficient information to reasonably estimate the fair value of an asset retirement obligation under FASB ASC 410-20. The Company provided an asset retirement obligation of $0.5 million and $0.5 million as of December 31, 2013 and 2012, respectively, related to the discontinued use of the Sabine Pass plant. The Company did not provide any asset retirement obligations for its other facilities because it did not have sufficient information as set forth in FASB ASC 410-20-25-16 to reasonably estimate such obligations, and the Company had no intention of discontinuing use of any significant assets. See Note 4 "Acquisition, Disposition, and Impairments" for further discussion of the Sabine Pass plant.
(k) Revenue Recognition
The Company recognizes revenue for sales or services at the time the natural gas, NGLs, condensate or crude oil are delivered or at the time the service is performed. The Company generally accrues one month of sales and the related gas, condensate and crude oil purchases and reverses these accruals when the sales and purchases are actually invoiced and recorded in the subsequent months. Actual results could differ from the accrual estimates. Purchase and sale arrangements are generally reported in revenues and costs on a gross basis in the consolidated statement of operations in accordance with FASB ASC 605-45-45-1. Except for fee based arrangements, the Partnership acts as the principal in these purchase and sale transactions, has the risk and reward of ownership as evidenced by title transfer, schedules the transportation and assumes credit risk. The Partnership conducts "off-system" gas marketing operations as a service to producers on systems that it does not own. It refers to these activities as part of energy trading activities. In some cases, the Partnership earns an agency fee from the producer for arranging the marketing of the producer's natural gas. In other cases, the Partnership purchases the natural gas from the producer and enters into a sales contract with another party to sell the natural gas. The revenue and cost of sales for these activities are included in revenue on a net basis in the consolidated statement of operations.
The Company accounts for taxes collected from customers attributable to revenue transactions and remitted to government authorities on a net basis (excluded from revenues).
(l) Comprehensive Income (Loss)
Comprehensive income includes net income (loss) and other comprehensive income, which includes unrealized gains and losses on derivative financial instruments. Pursuant to FASB ASC 815, the Company records deferred hedge gains and losses on its derivative financial instruments that qualify as cash flow hedges as other comprehensive income.
In February 2013, the FASB issued ASU 2013-2, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income ("ASU 2013-2”). ASU 2013-2 requires disclosure of amounts reclassified out of accumulated other comprehensive income ("AOCI") by component. In addition, an entity is required to present, either on the face of the statement where net income is presented or in the notes, significant amounts reclassified out of AOCI by the respective line items of net income but only if the amount reclassified is required to be reclassified to net income in its entirety in the same reporting period. For amounts not reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures that provide additional detail about those amounts. For the years ended December 31, 2013, 2012 and 2011, we reclassified cash flow hedge (gains) losses in the amounts of $(1.0) million, $(0.6) million and $1.8 million, respectively, included in other comprehensive income to revenues on the consolidated statements of operations.
(m) Derivatives
The Partnership uses derivatives to hedge against changes in cash flows related to product price, as opposed to their use for trading purposes. FASB ASC 815 requires that all derivatives be recorded on the balance sheet at fair value. It generally determines the fair value of futures contracts and swap contracts based on the difference between the derivative's fixed contract price and the underlying market price at the determination date. The asset or liability related to the derivative instruments is recorded on the balance sheet in fair value of derivative assets or liabilities.
Realized and unrealized gains and losses on commodity related derivatives that are not designated as hedges, as well as the ineffective portion of hedge derivatives, are recorded as gain or loss on derivatives in the consolidated statement of operations in the period incurred. Unrealized gains and losses on effective cash flow hedge derivatives are recorded as a component of accumulated other comprehensive income. When the hedged transaction occurs, the realized gain or loss on the hedge derivative is transferred from accumulated other comprehensive income to earnings. Realized gains and losses on commodity hedge derivatives are recognized in revenues. Settlements of derivatives are included in cash flows from operating activities.
(n) Concentrations of Credit Risk
Financial instruments, which potentially subject the Partnership to concentrations of credit risk, consist primarily of trade accounts receivable and derivative financial instruments. Management believes the risk is limited since the Partnership's customers represent a broad and diverse group of energy marketers and end users. In addition, the Partnership continually monitors and reviews credit exposure to its marketing counter-parties and letters of credit or other appropriate security are obtained as considered necessary to limit the risk of loss. The Partnership's records reserves for uncollectible accounts on a specific identification basis since there is not a large volume of late paying customers. The Partnership had a reserve for uncollectible receivables as of December 31, 2013 and 2012 of $0.6 million and $0.5 million, respectively.
During the years ended December 31, 2013, 2012, and 2011, the Partnership had only one customer that individually represented greater than 10.0% of its revenues. The customer is located in the LIG segment and represented 12.6%, 10.5% and 12.3% of consolidated revenue for each of the years ended December 31, 2013, 2012 and 2011, respectively. As the Partnership continues to grow and expand, the relationship between individual customer sales and consolidated total sales is expected to continue to change. While this customer represents a significant percentage of revenues, the loss of this customer would not have a material adverse impact on the Partnership's results of operations because the gross operating margin received from transactions with this customer is not material to the Partnership's gross operating margin.
(o) Legal Costs Expected to be Incurred in Connection with a Loss Contingency
Legal costs incurred in connection with a loss contingency are expensed as incurred.
(p) Environmental Costs
Environmental expenditures are expensed or capitalized as appropriate, depending on the nature of the expenditures and their future economic benefit. Expenditures that related to an existing condition caused by past operations that do not contribute to current or future revenue generation are expensed. Liabilities for these expenditures are recorded on an undiscounted basis (or a discounted basis when the obligation can be settled at fixed and determinable amounts) when environmental assessments or clean-ups are probable and the costs can be reasonably estimated. For the years ended December 31, 2013, 2012 and 2011, such expenditures were not significant.
(q) Share-Based Awards
The Company recognizes compensation cost related to all stock-based awards, including stock options, in its consolidated financial statements in accordance with FASB ASC 718. The Partnership and CEI each have similar unit or share-based payment plans for employees, which are described below. Share-based compensation associated with CEI's share-based compensation plans awarded to officers and employees of the general partner of the Partnership are recorded by the Partnership since CEI has no substantial or managed operating activities other than its interest in the Partnership. Amounts recognized in the consolidated financial statements with respect to these plans are as follows (in thousands):


		Years Ended December 31,
		2013			2012				2011
Cost of share-based compensation charged to general and administrative expense		$	12,546		$	8,240			$	6,405

Cost of share-based compensation charged to operating expense		1,837			1,243				1,151

Total amount charged to income		$	14,383		$	9,483			$	7,556

Interest of non-controlling partners in share-based compensation		$	5,656		$	3,813			$	3,052

Amount of related income tax benefit recognized in income		$	3,235		$	2,102			$	1,670

(r) Recent Accounting Pronouncements
We have reviewed all recently issued accounting pronouncements that became effective during the year ended December 31, 2013, and have determined that none would have a material impact on our Consolidated Financial Statements.

Public_Offering_of_Units_and_C

Public Offering of Units and Certain Provisions of the Partnership Agreement	12 Months Ended
	Dec. 31, 2013
Partners' Capital Notes [Abstract]	'
Partners' Capital Notes Disclosure [Text Block]	'
	(3) Public Offering of Units by CELP and Certain Provisions of the Partnership Agreement
	(a) Issuance of Preferred Units
	On January 19, 2010, the Partnership issued approximately $125.0 million of Series A Convertible Preferred Units (the "preferred units") to an affiliate of Blackstone/GSO Capital Solutions for net proceeds of $120.8 million. The Partnership's general partner made a contribution of $2.6 million in connection with the issuance to maintain its 2% general partner interest. The 14,705,882 preferred units were convertible by the holders thereof at any time into common units on a one-for-one basis, subject to certain adjustments in the event of certain dilutive issuances of common units. The preferred units were entitled to a quarterly distribution with a value that will be the greater of $0.2125 per unit or the amount of the quarterly distribution per unit paid to common unitholders, subject to certain adjustments. Income is allocated to the preferred units in an amount equal to the quarterly distribution with respect to the period earned. During 2012 and 2011, the Partnership paid distributions on its preferred units of $14.4 million and $17.2 million, respectively.
	Beginning in the third quarter of 2012 through the fourth quarter of 2013, distributions on the preferred units were paid-in-kind ("PIK"). The number of PIK preferred unit distributions is based on a fixed price of $13.25. The distributions for the year ended December 31, 2012 also included 366,260 of PIK preferred units and the distributions for the year ended December 31, 2013 were paid-in-kind through the issuance of 1,570,806 preferred units. A distribution on the preferred units of $0.36 per unit was declared for the three months ended December 31, 2013, which was also paid-in-kind on February 12, 2014 in the amount of 452,186 preferred units.
	The Partnership had the right to force conversion of the preferred units if (i) the daily volume weighted average trading price of the common units is greater than $12.75 per unit for 20 out of the trailing 30 trading days ending on two trading days before the date on which the Partnership delivers notice of such conversion, and (ii) the average trading volume of common units exceeds a specified number of common units (the “trading volume threshold”) for 20 out of the trailing 30 trading days ending on two trading days before the date on which the Partnership delivers notice of such conversion. On February 27, 2014, the board of directors of the Partnership’s general partner amended the Partnership’s partnership agreement to reduce the trading volume threshold from 250,000 common units to 215,000, and on that same date the Partnership delivered a notice of conversion of all outstanding preferred units.
	(b) Issuance of Common Units
	In June 2013, the Partnership issued 8,280,000 common units representing limited partner interests in the Partnership (including 1,080,000 common units issued pursuant to the exercise of the underwriters' option to purchase additional common units) at a public offering price of $20.33 per common unit for net proceeds of $162.0 million. In January 2013, the Partnership issued 8,625,000 common units representing limited partner interests in the Partnership at a public offering price of $15.15 per common unit for net proceeds of $125.5 million. Concurrently with the public offering, in a privately negotiated transaction, the Partnership issued 2,700,000 common units representing limited partner interest in the Partnership at an offering price of $14.55 per unit for net proceeds of $39.3 million. The net proceeds from both common unit offerings were used for capital expenditures for currently identified projects, including the Cajun-Sibon projects, and for general partnership purposes. Crosstex Energy GP, LLC did not exercise its option to make a general partner contribution to maintain its then current general partner percentage interest in connection with these offerings.
	In September 2012, the Partnership issued 5,660,378 common units representing limited partner interests in the Partnership at an offering price of $13.25 per unit for net proceeds of $74.8 million. The net proceeds from the common units issuance were used primarily to fund the Partnership's currently identified projects, including the Cajun-Sibon NGL pipeline expansion, and for general partnership purposes. Crosstex Energy GP, LLC did not exercise its option to make a general partner contribution to maintain its then current general partner percentage interest in connection with this offering.
	In May 2012, the Partnership issued 10,120,000 common units representing limited partner interests in the Partnership at a public offering price of $16.28 per unit for net proceeds of $158.0 million. In addition, Crosstex Energy GP, LLC made a general partner contribution of $3.4 million in connection with the issuance to maintain its then current general partner interest. The net proceeds from the common units offering were used for general partnership purposes.
	In March 2013, the Partnership entered into an Equity Distribution Agreement (the “ EDA”) with BMO Capital Markets Corp. (“BMOCM”). Pursuant to the terms of the EDA, the Partnership could sell from time to time through BMOCM, as its sales agent, common units representing limited partner interests having an aggregate offering price of up to $75.0 million. Sales of such common units could be made by means of ordinary brokers’ transactions through the facilities of the NASDAQ Global Select Market LLC at market prices, in block transactions or as otherwise agreed by BMOCM and the Partnership.

	In May 2013, the Partnership entered into an Equity Distribution Agreement ("Replacement EDA") with BMOCM. This EDA replaced the previous EDA. Pursuant to the terms of the Replacement EDA, the Partnership could sell from time to time through BMOCM, as its sales agent, common units representing limited partner interests having an aggregate offering price of up to $75.0 million. Sales of such common units could be made by means of ordinary brokers’ transactions through the facilities of the NASDAQ Global Select Market LLC at market prices, in block transactions or as otherwise agreed by BMOCM and the Partnership.

	Through December 31, 2013, the Partnership sold an aggregate of 1,181,628 common units and 3,348,213 common units under the EDA and Replacement EDA, respectively, generating proceeds of approximately $20.9 million and $72.3 million (net of approximately $0.3 million and $0.9 million of commissions to BMOCM), respectively. The Partnership used the net proceeds for general partnership purposes, including working capital, capital expenditures and repayments of indebtedness. The Partnership exhausted its capacity under the Replacement EDA on January 3, 2014.
	The Company reflects changes in its ownership interest in the Partnership as equity transactions. The carrying amount of the non-controlling interest is adjusted to reflect the change in the Company's ownership interest in the Partnership. Any difference between the fair value of the consideration received and the amount by which the non-controlling interest is adjusted is recognized in additional paid-in-capital. The Company's book carrying amount per Partnership unit was below the price per unit received by the Partnership for all of its sales of common units during 2013 and 2012, resulting in changes in equity of $35.1 million and $15.9 million, respectively. The changes were recorded as an increase in additional paid-in-capital and a reduction in non-controlling interest during the year ended December 31, 2013 and 2012. The Company also increased its deferred tax liability in the amount of $7.2 million during the year ended December 31, 2013 and decreased its deferred tax liability in the amount of $11.1 million during the year ended December 31, 2012 relating to the difference between its book and tax investment in the Partnership with the offset to additional paid in capital.
	(c) Cash Distributions
	Unless restricted by the terms of the Partnership's credit facility and/or senior unsecured note indentures, the Partnership must make distributions of 100% of available cash, as defined in the partnership agreement, within 45 days following the end of each quarter. As described under (a) Sale of Preferred Units above, the preferred units are entitled to a quarterly distribution equal to the greater of $0.2125 per unit or the amount of the quarterly distribution per unit paid to common unitholders, subject to certain adjustments. The general partner is not entitled to a distribution in relation to its percentage interest with respect to the quarterly preferred distribution of $0.2125 per unit that is made solely to the preferred unitholders. The general partner is entitled to a distribution in relation to its percentage interest with respect to all distributions made to common unitholders. If the distributions are in excess of $0.2125 per unit, distributions are made 100% to the common and preferred unitholders minus the general partner's percentage interest, subject to the payment of incentive distributions as described below to the extent that certain target levels of cash distributions are achieved.
	Under the quarterly incentive distribution provisions, generally the Partnership's general partner is entitled to 13% of amounts the Partnership distributes in excess of $0.25 per unit, 23% of the amounts the Partnership distributes in excess of $0.3125 per unit and 48% of amounts the Partnership distributes distribute in excess of $0.375 per unit. Incentive distributions totaling $6.4 million, $4.5 million and $2.4 million were earned by our general partner for the years ended 2013, 2012 and 2011, respectively. The Partnership paid annual distributions per common unit of $1.33, $1.31 and $1.17 in the years ended December 31, 2013, 2012 and 2011, respectively.
	The Partnership's fourth quarter distribution on its common units is $0.36 per unit which was paid February 14, 2014.
	(d) Allocation of Partnership Income
	Net income is allocated to Crosstex Energy GP, LLC, a wholly-owned subsidiary of the Company, as the Partnership's general partner in an amount equal to its incentive distributions as described in Note 3(c) above. The general partner's share of the Partnership's net income (loss) is reduced by stock-based compensation expense attributed to the Company's stock options and restricted stock awarded to officers and employees of the Partnership. The remaining net income (loss) after incentive distributions and Company-related stock-based compensation is allocated pro rata between a relational interest percentage of the general partner interest, the subordinated units (excluding senior subordinated units), and the common units. The following table reflects the Company's general partner share of the Partnership's net income (loss) (in thousands):



		Years Ended December 31,
		2013			2012			2011
	Income allocation for incentive distributions	$	6,390		$	4,489		$	2,372

	Stock-based compensation attributable to CEI's restricted shares	(6,973		)	(4,205		)	(3,119		)
	General partner interest in net income (loss)	(2,138		)	(818		)	15

	General partner share of net loss	$	(2,721	)	$	(534	)	$	(732	)
	The Company also owns limited partner common units. The Company's share of the Partnership's net income (loss) attributable to its limited partner common units was net loss of $27.6 million, $15.5 million and $6.4 million for the years ended December 31, 2013, 2012 and 2011, respectively.

Acquisitions_Disposition_and_I

Acquisitions, Disposition and Impairments	12 Months Ended
Acquisitions, Disposition and Impairments	Dec. 31, 2013
Business Acquisition Purchase Price Allocation Abstract [Abstract]	'
Mergers, Acquisitions and Dispositions Disclosures	'
	(4) Acquisition, Disposition and Impairments
	(a) Acquisition
	On July 2, 2012, the Partnership, through a wholly-owned subsidiary, acquired all of the issued and outstanding common stock of Clearfield. Clearfield was a well-established crude oil, condensate and brine services company with operations in Ohio, Kentucky and West Virginia. Clearfield's business included crude oil pipelines, a barge loading terminal on the Ohio River, a rail loading terminal on the Ohio Central Railroad network, a trucking fleet and brine disposal wells. All of these assets are now included in the Partnership's ORV segment.
	The Partnership paid approximately $215.4 million in cash (before working capital and certain purchase price adjustments) for the acquisition and the purchase was funded with proceeds from the senior notes offering in May 2012.
	Included in the Clearfield acquisition were three local distribution companies, or LDCs, which the Partnership marketed for sale and were classified as held for disposition on the balance sheet as of December 31, 2012. The Partnership chose not to apply discontinued operations presentation on the income statement as the related amounts were immaterial during the period of the Partnership's ownership. On October 15, 2012, the Partnership entered into an agreement to sell the LDCs for an amount of $19.4 million, and the sale was completed on January 18, 2013.
	The goodwill recognized from the Clearfield acquisition results primarily from the value of opportunity created from the strategic asset positioning in the Utica and Marcellus shale plays which provides the Partnership with a substantial growth platform in a new geographic area. The Partnership finalized the purchase price allocation related to the Clearfield acquisition during July 2013. As a result of the purchase price adjustments since December 31, 2012, the Partnership recognized an increase of goodwill acquired from the transaction of $1.2 million.
	The Partnership recognized intangible assets related to customer relationships. The acquired intangible assets will be amortized on a straight-line basis over the estimated customer life of approximately 20 years.
	The Partnership assumed a long-term liability related to additional benefit obligations. Also, the Partnership assumed a long-term liability related to inactive easement commitments for a period of 10 years.
	Purchase Price Allocation in Clearfield Acquisition
	The following table is a summary of the consideration paid in the Clearfield acquisition and the purchase price allocation for the fair value of the assets acquired and liabilities assumed at the acquisition date,:


	Purchase Price Allocation (in thousands):
	Purchase Price to Clearfield Energy, Inc.	$	215,397
	Purchase Price to Clearfield Energy, Inc.	$	215,397
	Total purchase price	$	215,397
	Total purchase price	$	215,397
	Assets acquired:
	Current assets	$	17,622
	Current assets	$	17,622
	Assets held for disposition	19,358
	Assets held for disposition	19,358
	Property, plant, and equipment	91,422
	Property, plant, and equipment	91,422
	Goodwill	153,802
	Goodwill	153,802
	Intangibles	37,600
	Intangibles	37,600
	Liabilities assumed:
	Current liabilities	(28,274		)
	Liabilities held for disposition	(1,400		)
	Deferred taxes	(65,228		)
	Long term liabilities	(9,505		)
	Total purchase price	$	215,397
	Total purchase price	$	215,397
	For the period from July 2, 2012 to December 31, 2012, the Partnership recognized $108.0 million of midstream revenue related to properties acquired in the Clearfield acquisition. For the period from July 2, 2012 to December 31, 2012, the Partnership recognized $94.2 million of operating costs and expenses related to properties acquired in the Clearfield acquisition.
	Pro Forma Information
	The following unaudited pro forma condensed financial data for the year ended December 31, 2012 and 2011 gives effect to the Clearfield acquisition as if it had occurred on January 1, 2011. The unaudited pro forma condensed financial information has been included for comparative purposes only and is not necessarily indicative of the results that might have occurred had the transactions taken place on the dates indicated and is not intended to be a projection of future results.


			Year Ended
			31-Dec-12			31-Dec-11
			(in thousands except for per unit data)
	Pro forma total revenues		$	1,897,199		$	2,266,868
	Pro forma total revenues		$	1,897,199		$	2,266,868
	Pro forma net loss		$	(39,021	)	$	(15,476	)
	Pro forma net loss attributable to Crosstex Energy, Inc.		$	(14,762	)	$	(8,460	)
	Pro forma net loss per common unit:
	Basic and Diluted		$	(0.30	)	$	(0.18	)
	(b) Intangible Asset Impairment
	In August 2013, the Partnership shut down the Eunice processing plant, which is located in south Louisiana and is part of our PNGL segment, due to adverse economics driven by low NGL prices and low processing volumes which we do not see improving in the near future based on forecasted pricing. The Partnership recorded an impairment expense of $72.6 million during the third quarter of 2013 related to the intangible assets for the terminated customer relationships attributable to the plant shut down.
	(c) Long-Lived Assets Impairments
	Changes in Operations During 2013 and 2012.
	The Partnership's Sabine Pass plant held a contract with a third-party to fractionate the raw-make NGLs produced by the Sabine Pass plant. The primary term of the contract expired in March 2012 and was renewed on a month-to-month basis during the remainder of 2012. Due to the anticipated termination of this third-party fractionation agreement in early 2013, the Partnership began accelerating depreciation of this facility during the third quarter of 2012. The plant also had some equipment failures during the fourth quarter of 2012. In January 2013, the Partnership ceased plant operations because the cost to repair the equipment could not be supported by an existing month-to-month fractionation agreement. Depreciation and amortization expense during the fourth quarter of 2012 was changed to accelerate the remaining non-recoverable costs associated with the plant. Total depreciation and amortization of $28.9 million was recognized for the Sabine Pass plant during 2012. The Sabine Pass plant contributed gross operating margin of $2.0 million and $2.7 million for the years ended December 31, 2012 and 2011, respectively. The net book value for the plant is $18.9 million as of December 31, 2013 and represents the plant's fair market value. Although the Partnership does not have specific plans at this time to relocate the Sabine Pass plant, it may utilize it elsewhere in its operations.

LongTerm_Debt

Long-Term Debt	12 Months Ended
Long-Term Debt	Dec. 31, 2013
Long-term Debt, by Current and Noncurrent [Abstract]	'
Long Term Debt	'
	(5) Long-Term Debt
	As of December 31, 2013 and 2012, long-term debt consisted of the following (in thousands):


			2013			2012
	Partnership's bank credit facility (due 2016), interest based on Prime and/or LIBOR plus an applicable margin, interest rate at December 31, 2013 and December 31, 2012 was 3.2% and 4.3%, respectively		$	155,000		$	71,000
			$	155,000		$	71,000
	Subsidiary Borrower's credit facility (due 2016), interest based on LIBOR plus 5.0%, interest rate at December 31, 2013 was 5.3%		65,041			—
			65,041			—
	Senior unsecured notes (due 2018), net of discount of $7.8 million and $9.7 million, respectively, which bear interest at the rate of 8.875%		717,202			715,305
			717,202			715,305
	Senior unsecured notes (due 2022), which bear interest at the rate of 7.125%		250,000			250,000
			250,000			250,000
	Other debt		13,229			—
	Other debt		13,229			—
	Debt classified as long-term		$	1,200,472		$	1,036,305
	Debt classified as long-term		$	1,200,472		$	1,036,305
	Maturities. Maturities for the long-term debt as of December 31, 2013 are as follows (in thousands):


	2014	$	—
	2014	$	—
	2015	—
	2015	—
	2016	232,734
	2016	232,734
	2017	536
	2017	536
	2018	725,000
	2018	725,000
	Thereafter	250,000
	Thereafter	250,000
	Subtotal	1,208,270
	Subtotal	1,208,270
	Less discount	(7,798		)
	Total outstanding debt	$	1,200,472
	Total outstanding debt	$	1,200,472

	The Partnership’s Existing Credit Facility. In January, 2013, the Partnership amended the existing credit facility to, among other things, eliminate the existing and any future step-up in the maximum permitted consolidated leverage ratio for acquisitions. All references herein to the Partnership's existing credit facility include, as applicable, such amendments.
	In August 2013, the Partnership amended the existing credit facility to, among other things, (i) allow the Partnership to make additional investments in joint ventures and subsidiaries that are not guarantors of the Partnership's obligations under the existing credit facility, (ii) decrease the minimum consolidated interest coverage ratio (as defined in the existing credit facility, being generally computed as the ratio of consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges to consolidated interest charges) and (iii) increase the maximum permitted consolidated leverage ratio (as defined in the existing credit facility, being generally computed as the ratio of total funded debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges). See the chart below for the ratios, as amended.

	In January 22, 2014, the Partnership amended the existing credit facility to redefine the credit agreement's definition of "change of control" such that the consummation of the previously announced business combination with Devon Energy Corporation will not constitute a change of control under the existing credit agreement.
	As of December 31, 2013, there was $155.0 million of borrowing and $59.7 million in outstanding letters of credit under the existing credit facility leaving approximately $420.3 million available for future borrowing based on a borrowing capacity of $635.0 million. However, the financial covenants in the existing credit facility limit the amount of funds that the Partnership can borrow. As of December 31, 2013, based on the financial covenants in the existing credit facility, the Partnership could borrow approximately $207.1 million of additional funds.
	The Partnership’s existing credit facility is guaranteed by substantially all of the Partnership’s subsidiaries and is secured by first priority liens on substantially all of its assets and those of the guarantors, including all material pipeline, gas gathering and processing assets, all material working capital assets and a pledge of all of the Partnership’s equity interests in substantially all of its subsidiaries. The Partnership may prepay all loans under the Partnership’s existing credit facility at any time without premium or penalty (other than customary LIBOR breakage costs), subject to certain notice requirements. The Partnership’s existing credit facility requires mandatory prepayments of amounts outstanding thereunder with the net proceeds of certain asset sales, extraordinary receipts, equity issuances and debt incurrences, but these mandatory prepayments do not require any reduction of the lenders’ commitments under the Partnership’s existing credit facility.
	Under the existing credit facility, borrowings bear interest at the Partnership's option at the Eurodollar Rate (the British Bankers Association LIBOR Rate) plus an applicable margin or the Base Rate (the highest of the Federal Funds Rate plus 0.50%, the 30-day Eurodollar Rate plus 1.0%, or the administrative agent's prime rate) plus an applicable margin. The Partnership pays a per annum fee (as described below) on all letters of credit issued under the existing credit facility and a commitment fee of between 0.375% and 0.50% per annum on the unused availability under the existing credit facility. The commitment fee, letter of credit fee and the applicable margins for the interest rate vary quarterly based on the Partnership's leverage ratio (as defined in the existing credit facility, being generally computed as the ratio of total funded debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges) and are as follows:


	Leverage Ratio		Base Rate		Eurodollar	Letter of
			Loans		Rate	Commitment
					Loans and	Fees
					Letter of Credit
					Fees
	Greater than or equal to 4.50 to 1.00		2.00%		3.00%	0.50%
	Greater than or equal to 4.00 to 1.00 and less than 4.50 to 1.00		1.75%		2.75%	0.50%
	Greater than or equal to 3.50 to 1.00 and less than 4.00 to 1.00		1.50%		2.50%	0.50%
	Greater than or equal to 3.00 to 1.00 and less than 3.50 to 1.00		1.25%		2.25%	0.50%
	Less than 3.00 to 1.00		1.00%		2.00%	0.38%
	The existing credit facility includes financial covenants that are tested on a quarterly basis, based on the rolling four-quarter period that ends on the last day of each fiscal quarter. The minimum consolidated interest coverage ratio (as defined in the existing credit facility, but generally computed as the ratio of total funded debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges to consolidated interest charges) is 2.25 to 1.0 for the fiscal quarters ending March 31, 2014, June 30, 2014, September 30, 2014 and December 31, 2014, with a minimum ratio of 2.50 to 1.0 for each fiscal quarter thereafter. The maximum permitted senior leverage ratio (as defined in the existing credit facility, but generally computed as the ratio of total secured funded debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non cash charges) is 2.75 to 1.0. The maximum permitted leverage ratio (as defined in the existing credit facility, but generally computed as the ratio total funded debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges) is 5.50 to 1.0 for the fiscal quarters ending March 31, 2014, June 30, 2014 and September 30, 2014, with a maximum ratio of 5.25 to 1.0 for each fiscal quarter ending thereafter.
	In addition, the existing credit facility contains various covenants that, among other restrictions, limit the Partnership's ability to:

	•	grant or assume liens;

	•	make investments;

•	incur or assume indebtedness;

•	engage in mergers or acquisitions;

•	sell, transfer, assign or convey assets;

•	repurchase the Partnership's equity, make distributions and certain other restricted payments;

•	change the nature of the Partnership's business;

•	engage in transactions with affiliates;

•	enter into certain burdensome agreements;

•	make certain amendments to the omnibus agreement or the Partnership's subsidiaries' organizational documents;

•	prepay the senior unsecured notes and certain other indebtedness; and

•	enter into certain hedging contracts.
The existing credit facility permits the Partnership to make quarterly distributions to unitholders so long as no default exists under the existing credit facility.
Each of the following is an event of default under the existing credit facility:

•	failure to pay any principal, interest, fees, expenses or other amounts when due;

•	failure to meet the quarterly financial covenants;

•	failure to observe any other agreement, obligation, or covenant in the existing credit facility or any related loan document, subject to cure periods for certain failures;

•	the failure of any representation or warranty to be materially true and correct when made;

•	The Partnership's or any of its subsidiaries default under other indebtedness that exceeds a threshold amount;

•	judgments against the Partnership or any of its material subsidiaries, in excess of a threshold amount;

•	certain ERISA events involving the Partnership or any of its material subsidiaries, in excess of a threshold amount;

•	bankruptcy or other insolvency events involving the Partnership or any of its material subsidiaries; and

•	a change in control (as defined in the existing credit facility).
If an event of default relating to bankruptcy or other insolvency events occurs, all indebtedness under the existing credit facility will immediately become due and payable. If any other event of default exists under the existing credit facility, the lenders may accelerate the maturity of the obligations outstanding under the existing credit facility and exercise other rights and remedies. In addition, if any event of default exists under the existing credit facility, the lenders may commence foreclosure or other actions against the collateral.
If any default occurs under the existing credit facility, or if the Partnership is unable to make any of the representations and warranties in the existing credit facility, the Partnership will be unable to borrow funds or have letters of credit issued under the existing credit facility.
The Partnership expects to be in compliance with the covenants in the existing credit facility for at least the next twelve months.
Subsidiary Borrower’s Credit Facility. On March 5, 2013, XTXI Capital, LLC, a wholly-owned subsidiary of the Company (“Subsidiary Borrower”), entered into a Credit Agreement (the “Subsidiary Credit Agreement”) with Citibank, N.A., as Administrative Agent, Collateral Agent and a Lender, and the other lenders party thereto. The Subsidiary Credit Agreement initially permitted Subsidiary Borrower to borrow up to $75.0 million on a revolving credit basis. The maturity date of the Subsidiary Credit Agreement is March 5, 2016.

In May 2013, Subsidiary Borrower exercised the accordion feature of the Subsidiary Credit Agreement, thereby increasing the amount Subsidiary Borrower is permitted to borrow on a revolving credit basis from $75.0 million to up to $90.0 million. Subsidiary Borrower intends to distribute these additional funds for the Company's investment commitment in E2. As of December 31, 2013, there was $65.0 million borrowed under the Subsidiary Credit Agreement, leaving approximately $25.0 million available for future borrowing based on the borrowing capacity of $90.0 million.

Subsidiary Borrower’s obligations under the Subsidiary Credit Agreement are guaranteed by the Company (the “Guaranty”) and are secured by a first priority lien on 10,700,000 common units in the Partnership, which common units were contributed by the Company to Subsidiary Borrower (together with any additional common units subsequently pledged as collateral under the Subsidiary Credit Agreement, the “Pledged Units”).

Borrowings under the Subsidiary Credit Agreement bear interest at a per annum rate equal to the reserve-adjusted British Banks Association LIBOR Rate plus 5.00%. Subsidiary Borrower pays a commitment fee of 0.75% per annum on the unused availability under the Subsidiary Credit Agreement. Subject to the $90.0 million cap on outstanding borrowings and the percentage obtained by dividing (A) the total net outstanding borrowings under the Subsidiary Credit Agreement by (B) the product of (x) the number of Common Units included in the Pledged Units on such date and (y) the closing sale price per Common Unit on such date (the “Loan to Equity Value Percentage”) not equaling or exceeding 47%, Subsidiary Borrower may elect to pay interest, fees and expenses in connection with the Subsidiary Credit Agreement in kind by adding such amounts to the principal amount of the borrowings under the Subsidiary Credit Agreement.

The Subsidiary Credit Agreement requires mandatory prepayments of all amounts outstanding thereunder if the Company ceases to own all of the equity interests of Subsidiary Borrower. In addition, if the Loan to Equity Value Percentage exceeds 47%, Subsidiary Borrower must prepay the loan, pledge additional Common Units as collateral and/or direct the collateral agent to sell Pledged Units to achieve a Loan to Equity Value Percentage that is less than 42.5%.

The Subsidiary Credit Agreement prohibits Subsidiary Borrower from making any distributions or other payments to the Company (including any distributions resulting from Subsidiary Borrower’s receipt of distributions from the Partnership) if the Loan to Equity Value Percentage exceeds 47% or any event of default exists under the Subsidiary Credit Agreement. The Subsidiary Credit Agreement also limits the Company’s ability and the ability of its subsidiaries (other than the Partnership) to sell Common Units in certain circumstances.

The Subsidiary Credit Agreement contains various other covenants that, among other restrictions, limit Subsidiary Borrower’s ability to incur indebtedness, enter into acquisition or disposition transactions and engage in any business activities. The Subsidiary Credit Agreement does not include any financial covenants.

In January 2014, the Subsidiary Borrower received a limited consent that the transactions contemplated by the Merger Agreement and the Contribution Agreement shall not constitute an issuer change of control or issuer merger event within the meaning given to such terms in the Subsidiary Credit Agreement.

Events of default under the Subsidiary Credit Agreement include, among others, (i) Subsidiary Borrower’s failure to pay principal or interest when due, (ii) Subsidiary Borrower’s or the Company’s failure to comply with agreements, obligations or covenants in the Subsidiary Credit Agreement, the Guaranty or any other loan document, (iii) material inaccuracy of any representation or warranty, (iv) certain change of control events (other than with respect to the proposed business combination with Devon, for which the Subsidiary Borrower has obtained a waiver), bankruptcy and other insolvency events and (v) the occurrence of certain events relating to the Common Units.

If an event of default relating to bankruptcy or other insolvency events occur, all indebtedness under the Subsidiary Credit Agreement will immediately become due and payable. If any other event of default exists under the Subsidiary Credit Agreement, the lenders may accelerate the maturity of the obligations outstanding under the Subsidiary Credit Agreement, Subsidiary Borrower will be unable to borrow funds and the lenders may exercise other rights and remedies. In addition, if any event of default exists under the Subsidiary Credit Agreement, the lenders may commence foreclosure or other actions against the Pledged Units. If the Company defaults on its obligations under the Guaranty, then the lenders could declare all amounts outstanding under the Subsidiary Credit Agreement immediately due and payable (with accrued interest). If Subsidiary Borrower and the Company are unable to pay such amounts, the lenders may foreclose on the Pledged Units. Citibank, N.A., as the agent under the Subsidiary Credit Agreement, has the right to demand additional collateral or amend the Subsidiary Credit Agreement if certain events occur that adversely impact the composition and quality of the Pledged Units or Citibank, N.A’s position as a secured creditor.

Other Borrowings. On September 4, 2013, E2 Energy Services LLC ("E2 Services"), one of the Ohio services companies in which the Company invests, entered into a credit agreement with JPMorgan Chase Bank ("JPMorgan"). The maturity date of the credit agreement is September 4, 2016. As of December 31, 2013, there was $12.7 million borrowed under the agreement, leaving approximately $7.3 million available for future borrowing based on borrowing capacity of $20.0 million. The interest rate under the credit agreement is based on Prime plus an applicable margin. The effective interest rate as of December 31, 2013 was approximately 4.2%. Additionally, as of December 31, 2013, E2 Services had certain promissory notes outstanding related to its vehicle fleet in the amount of $0.5 million due in increments through July 2017. The notes bear interest at fixed rates ranging 3.9% to 7.0%. CEI does not guarantee E2 Services debt obligations.
Senior Unsecured Notes. On February 10, 2010, the Partnership and Crosstex Energy Finance Corporation issued $725.0 million in aggregate principal amount of 8.875% senior unsecured notes (the "2018 Notes") due on February 15, 2018 at an issue price of 97.907% to yield 9.25% to maturity including the original issue discount (OID). Interest payments on the 2018 Notes are due semi-annually in arrears in February and August. On May 24, 2012, the Partnership and Crosstex Energy Finance Corporation issued $250.0 million in aggregate principal amount of 7.125% senior unsecured notes (the "2022 Notes" and together with the 2018 Notes, the "Senior Notes") due on June 1, 2022 at an issue price of 100% of the principal amount to yield 7.125% to maturity. The interest payments on the 2022 Notes are due semi-annually in arrears in June and December.
The indentures governing the Senior Notes contain covenants that, among other things, limit the Partnership's ability and the ability of certain of its subsidiaries to:

•	sell assets including equity interests in its subsidiaries;

•	pay distributions on, redeem or repurchase units or redeem or repurchase its subordinated debt (as discussed in more detail below);

•	make investments;

•	incur or guarantee additional indebtedness or issue preferred units;

•	create or incur certain liens;

•	enter into agreements that restrict distributions or other payments from its restricted subsidiaries to the Partnership;

•	consolidate, merge or transfer all or substantially all of its assets;

•	engage in transactions with affiliates;

•	create unrestricted subsidiaries;

•	enter into sale and leaseback transactions; or

•	engage in certain business activities.
The indentures provide that if the Partnership's fixed charge coverage ratio (the ratio of consolidated cash flow to fixed charges, which generally represents the ratio of adjusted EBITDA to interest charges with further adjustments as defined per the indenture) for the most recently ended four full fiscal quarters is not less than 2.0 to 1.0, the Partnership will be permitted to pay distributions to its unitholders in an amount equal to available cash from operating surplus (each as defined in our partnership agreement) with respect to its preceding fiscal quarter plus a number of items, including the net cash proceeds received by the Partnership as a capital contribution or from the issuance of equity interests since the date of the indenture, to the extent not previously expended. If the Partnership's fixed charge coverage ratio is less than 2.0 to 1.0, the Partnership will be able to pay distributions to its unitholders in an amount equal to a specified basket (less amounts previously expended pursuant to such basket), plus the same number of items discussed in the preceding sentence to the extent not previously expended. The Partnership was in compliance with this covenant as of December 31, 2013.
If the Senior Notes achieve an investment grade rating from each of Moody's Investors Service, Inc. and Standard & Poor's Ratings Services, many of the covenants discussed above will terminate. Our current ratings on our bonds from Moody's Investors Service, Inc. and Standard & Poor's Rating Services are B1 and B+, respectively.
On or after February 15, 2014, the Partnership may redeem all or a part of the notes at redemption prices (expressed as percentages of principal amount) equal to 104.438% for the twelve-month period beginning on February 15, 2014, 102.219% for the twelve-month period beginning February 15, 2015 and 100.00% for the twelve-month period beginning on February 15, 2016 and at any time thereafter, plus accrued and unpaid interest, if any, to the applicable redemption date on the notes.
The Partnership may redeem up to 35% of the 2022 Notes at any time prior to June 1, 2015 in an amount not greater than the cash proceeds from equity offerings at a redemption price of 107.125% of the principal amount of the 2022 Notes (plus accrued and unpaid interest to the redemption date) provided that:

•	at least 65% of the aggregate principal amount of the 2022 Notes remains outstanding immediately after the occurrence of such redemption; and

•	the redemption occurs within 180 days of the date of the closing of the equity offering.

Prior to June 1, 2017, the Partnership may redeem all or a part of the remaining 2022 Notes at the redemption price equal to the sum of the principal amount thereof, plus a make-whole premium at the redemption date, plus accrued and unpaid interest to the redemption date.
On or after June 1, 2017, the Partnership may redeem all or a part of the remaining 2022 Notes at redemption prices (expressed as percentages of principal amount) equal to 103.563% for the twelve-month period beginning on June 1, 2017, 102.375% for the twelve-month period beginning on June 1, 2018, 101.188% for the twelve-month period beginning on June 1, 2019 and 100.000% for the twelve-month period beginning on June 1, 2020 and at any time thereafter, plus accrued and unpaid interest, if any, to the applicable redemption date on the 2022 Notes.
Each of the following is an event of default under the indenture:

•	failure to pay any principal or interest when due;

•	failure to observe any other agreement, obligation, or other covenant in the indenture, subject to the cure periods for certain failures;

•	the Partnership's or any of its subsidiaries' default under other indebtedness that exceeds a certain threshold amount;

•	failures by the Partnership or any of its subsidiaries to pay final judgments that exceed a certain threshold amount; and

•	bankruptcy or other insolvency events involving the Partnership or any of its material subsidiaries.
If an event of default relating to bankruptcy or other insolvency events occurs, the Senior Notes will immediately become due and payable. If any other event of default exists under the indenture, the trustee under the indenture or the holders of the Senior Notes may accelerate the maturity of the Senior Notes and exercise other rights and remedies.
Successful completion of the Contribution and the Mergers would trigger a mandatory repurchase offer under the terms of the indenture governing the Partnership's 2018 Notes at a purchase price equal to 101% of the aggregate principal amount of the 2018 Notes repurchased, plus accrued and unpaid interest, if any. In certain circumstances, completion of the Contribution and the Mergers also could trigger a mandatory repurchase offer under the terms of the indenture governing the Partnership's 2022 Notes if, within 90 days of consummation of the transactions, the Partnership experiences a rating downgrade of the 2022 Notes by either Moody’s or S&P. The Partnership intends to fulfill its obligations with respect to the mandatory repurchase offer of the 2018 Notes and, if necessary, the 2022 Notes, following the closing of the Contribution and the Mergers in accordance with the terms of the applicable indenture.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	(6) Income Taxes
	The Company provides for income taxes using the liability method. Accordingly, deferred taxes are recorded for the differences between the tax and book basis that will reverse in future periods (in thousands).


			Years Ended December 31,
			2013			2012			2011
	Current tax provision		$	7,789		$	1,742		$	1,772

	Deferred tax (benefit)		(18,003		)	(8,384		)	(4,540		)
	Tax benefit		$	(10,214	)	$	(6,642	)	$	(2,768	)
	A reconciliation of the provision for income taxes is as follows (in thousands):


			Years Ended December 31,
			2013			2012			2011
	Federal income tax on taxable corporation at statutory rate (35%)		$	(13,840	)	$	(6,692	)	$	(3,071	)
	State income tax, net		(818		)	(396		)	(182		)
	Non-deductible expenses		4,282			258			153

	Other		162			188			332

	Income tax benefit		$	(10,214	)	$	(6,642	)	$	(2,768	)
	The principal component of the Company's net deferred tax liability is as follows (in thousands):


			Years Ended
			December 31,
			2013			2012
	Deferred income tax assets:

	Accrued expenses		$	1,251		$	1,455

	Deferred transaction cost		—			863

	Net operating loss carryforward—non-current		49,499			51,488

	Investment in the Partnership		—			5,981

	Other comprehensive income		61			—

	Alternative minimum tax carry forward (AMT)		8			8

			50,819			59,795

	Less: valuation allowance		—			(5,981		)

			50,819			53,814


	Deferred income tax liabilities:
	Property, plant, equipment, and intangible assets-current		—			(7,075		)

	Property, plant, equipment, and intangible assets-long-term		(176,471		)	(184,889		)
	Other Comprehensive income		—			(56		)

	Other		(3,405		)	(2,424		)
			(179,876		)	(194,444		)
	Net deferred tax liability		$	(129,057	)	$	(140,630	)
	At December 31, 2013 the Company had a net operating loss carryforward of approximately $130.2 million that expires from 2027 through 2033. The Company also has various state net operating loss carryforwards of approximately $76.5 million which will begin expiring in 2027. Management believes that it is more likely than not that the future results of operations will generate sufficient taxable income to utilize these net operating loss carryforwards before they expire. Although the Company has generated net operating losses in the past, the Company expects to have future taxable income from its investment in the Partnership, generated by the remedial allocations of income among the unitholders and the income generated by operations including the effect of reversals of accelerated depreciation.
	Deferred tax liabilities relating to property, plant, equipment and intangible assets represent, primarily, the Company's share of the book basis in excess of tax basis for assets inside of the Partnership. At December 31, 2012, the difference between the Company’s book and tax basis in its investment in the Partnership was a deferred tax asset of $6.0 million which was offset by a valuation allowance of $6.0 million. As of December 31, 2013, the difference between the Company’s book and tax basis in its investment in the Partnership was a deferred tax liability due to the changes in the Company’s investment as a result of the Partnership’s unit issuances during 2013. Since, the Company no longer has a deferred tax asset, the related $6.0 million valuation allowance was reversed during the year ended December 31, 2013. The Company adjusts its deferred tax liability with the offset to additional-paid-in-capital for changes in its investment in the Partnership due to unit issuances.
	The Company adopted the provisions of FASB ASC 740-10-25-16 on January 1, 2007. A reconciliation of the beginning and ending amount of the unrecognized tax benefits is as follows (In thousands):



Balance as of December 31, 2011	$	2,650

Decreases related to prior year tax positions	(383		)
Increases related to current year tax positions	320

Balance as of December 31, 2012	$	2,587

Decreases related to prior year tax positions	(712		)
Increases related to current year tax positions	519

Balance as of December 31, 2013	$	2,394

Unrecognized tax benefits of $2.4 million, if recognized, would affect the effective tax rate. It is unknown when this uncertain tax position will be resolved. In the event additional interest and penalties are incurred prior to resolution, per company policy, such penalties and interest will be recorded to income tax expense.
At December 31, 2013, tax years 2009 through 2013 remain subject to examination by the Internal Revenue Services and tax years 2008 through 2013 remain subject to examination by various state taxing authorities.

Employee_Incentive_Plan

Employee Incentive Plan	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Employee Incentive	'
	(7) Employee Incentive Plans
	(a) Long-Term Incentive Plans
	The Company accounts for share-based compensation in accordance with FASB ASC 718, which requires that compensation related to all stock-based awards, including stock options, be recognized in the consolidated financial statements. On May 9, 2013, the Partnership’s unitholders approved the amendment and restatement of the Crosstex Energy GP, LLC Long-Term Incentive Plan (the “Plan”), which increased the number of common units representing limited partner interests in the Partnership authorized for issuance under the Plan by 3,470,000 common units to an aggregate of 9,070,000 common units and made certain other technical amendments.
	(b) Partnership Restricted Incentive Units
	Awards of restricted incentive units are rights that entitle the grantee to receive common units of the Partnership upon the vesting of such restricted incentive unit. In addition, the restricted incentive units will become exercisable upon a change of control of the Partnership or its general partner.
	The restricted incentive units are intended to serve as a means of incentive compensation for performance and not primarily as an opportunity to participate in the equity appreciation of the common units. Therefore, plan participants will not pay any consideration for the common units they receive and the Partnership will receive no remuneration for the units. The restricted incentive units include a tandem award that entitles the participant to receive cash payments equal to the cash distributions made by the Partnership with respect to its outstanding common units until the restriction period is terminated or the restricted incentive units are forfeited. The restricted incentive units granted in 2013, 2012 and 2011 generally cliff vest after three years of service.
	The restricted incentive units are valued at their fair value at the date of grant which is equal to the market value of common units on such date. A summary of the restricted incentive unit activity for the year ended December 31, 2013 is provided below:


	Crosstex Energy, L.P. Restricted Incentive Units:		Number of				Weighted
			Units				Average
							Grant-Date
							Fair Value
	Non-vested, beginning of period		1,003,159				$	13.31

	Granted		625,339				16.19

	Vested*		(396,927		)		9.5

	Forfeited		(52,648		)		13.52

	Non-vested, end of period		1,178,923				$	16.11

	Aggregate intrinsic value, end of period (in thousands)		$	32,358

	_______________________________________________________________________________

	*	Vested units include 114,831 units withheld for payroll taxes paid on behalf of employees.

	In March 2013, the Partnership issued 57,897 restricted incentive units with a fair value of $1.0 million to officers and certain employees as bonus payments for 2012, which vested immediately and are included in the restricted incentive units granted and vested line items above.
	A summary of the restricted incentive units' aggregate intrinsic value (market value at vesting date) and fair value of units vested (market value at date of grant) during the years ended December 31, 2013, 2012 and 2011 are provided below (in thousands):


			Years Ended December 31,
	Crosstex Energy, L.P. Restricted Incentive Units:		2013				2012				2011
	Aggregate intrinsic value of units vested		$	6,750			$	3,850			$	6,438

	Fair value of units vested		$	3,771			$	2,097			$	5,945

	As of December 31, 2013, there was $7.4 million of unrecognized compensation cost related to non-vested restricted incentive units. That cost is expected to be recognized over a weighted-average period of 1.2 years.
	(c) Partnership Unit Options
	Unit options will have an exercise price that is not less than 100% of the fair market value of the units on the date of grant. In general, unit options granted will become exercisable over a period determined by the compensation committee. In addition, unit options will become exercisable upon a change in control of the Partnership or its general partner.
	The fair value of each unit option award is estimated at the date of grant using the Black-Scholes-Merton model. This model is based on the assumptions summarized below. Expected volatilities are based on historical volatilities of the Partnership's traded common units. The Partnership has used historical data to estimate share option exercise and employee departure behavior to estimate expected forfeiture rates. The expected life of unit options represents the period of time that unit options granted are expected to be outstanding. The risk-free interest rate for periods within the expected term of the unit option is based on the U.S. Treasury yield curve in effect at the time of the grant. The Partnership used the simplified method to calculate the expected term.
	Unit options are generally awarded with an exercise price equal to the market price of the Partnership's common units at the date of grant. The unit options granted generally vest based on 3 years of service (one-third after each year of service). There have been no options granted since 2009.
	A summary of the unit option activity for the years ended December 31, 2013, 2012, and 2011 is provided below:


			Years Ended December 31,
			2013								2012						2011
			Number of				Weighted				Number of			Weighted			Number of			Weighted
			Units				Average				Units			Average			Units			Average
							Exercise							Exercise						Exercise
							Price							Price						Price
	Outstanding, beginning of period		349,018				$	7.25			451,574			$	6.99		611,311			$	6.77

	Exercised		(151,795		)		5.5				(87,857		)	4.96			(128,477		)	4.61

	Forfeited		(3,109		)		23.6				(14,699		)	13.39			(31,260		)	12.83

	Outstanding, end of period		194,114				$	8.36			349,018			$	7.25		451,574			$	6.99

	Options exercisable at end of period		194,114				$	8.36			286,715			$	7.52		315,742			$	7.42

Weighted average contractual term (years) end of period:
Options outstanding		5.2								6.1						7.2

Options exercisable		5.2								6						6.9

Aggregate intrinsic value end of period (in thousands):
Options outstanding		$	3,829							$	3,016					$	4,648

Options exercisable		$	3,829							$	2,483					$	3,260

A summary of the unit options intrinsic value exercised (market value in excess of exercise price at date of exercise) and fair value of units vested (value per Black-Scholes-Merton option pricing model at date of grant) during the years ended December 31, 2013, 2012 and 2011 is provided below (in thousands):


		Years Ended December 31,
Crosstex Energy, L.P. Unit Options:		2013				2012				2011
Intrinsic value of units options exercised		$	2,104			$	988			$	1,527

Fair value of unit options vested		$	254			$	277			$	563

As of December 31, 2013, all options were vested and fully expensed.
(d) Crosstex Energy, Inc.'s Restricted Stock
The Crosstex Energy, Inc. long-term incentive plans provide for the award of restricted stock (collectively, "Awards") for up to 8,975,000 shares of Crosstex Energy, Inc.'s common stock. On May 9, 2013, CEI's stockholders approved the amendment and restatement of the Crosstex Energy, Inc. 2009 Long-Term Incentive Plan (the “CEI Plan”), which increased the number of shares of CEI's common stock authorized for issuance under the CEI Plan by 1,785,000 shares to an aggregate of 4,385,000 shares of common stock and made certain other technical amendments.
As of January 1, 2014, approximately 2,464,665 shares remained available under the long-term incentive plans for future issuance to participants. The maximum number of shares set forth above are subject to appropriate adjustment in the event of a recapitalization of the capital structure of Crosstex Energy, Inc. or reorganization of Crosstex Energy, Inc. Awards that are forfeited, terminated or expire unexercised become immediately available for additional awards under the long-term incentive plan.
CEI's restricted shares are included at their fair value at the date of grant which is equal to the market value of the common stock on such date. CEI's restricted stock granted in 2013, 2012 and 2011 generally cliff vest after three years of service. A summary of the restricted stock activity which includes officers and employees of the Partnership and directors of the general partner of the Partnership for the year ended December 31, 2013, is provided below:


Crosstex Energy, Inc. Restricted Shares:		Number of				Weighted
		Shares				Average
						Grant-Date
						Fair Value
Non-vested, beginning of period		1,329,162				$	9.75

Granted		632,912				15.08

Vested*		(445,177		)		7.43

Forfeited		(63,864		)		11.69

Non-vested, end of period		1,453,033				$	12.69

Aggregate intrinsic value, end of period (in thousands)		$	51,089

_______________________________________________________________________________
* Vested shares include 123,791 shares withheld for payroll taxes paid on behalf of employees.
In March 2013, CEI issued 60,018 restricted shares with a fair value of $1.0 million to officers and certain employees as bonus payments for 2012, which vested immediately and are included in restricted shares granted and vested in the above line items.
A summary of the restricted shares' aggregate intrinsic value (market value at vesting date) and fair value of shares vested (market value at date of grant) during the years ended December 31, 2013, 2012 and 2011 is provided below (in thousands):


		Years Ended December 31,
Crosstex Energy, Inc. Restricted Shares:		2013				2012				2011
Aggregate intrinsic value of shares vested		$	7,593			$	4,099			$	3,915

Fair value of shares vested		$	3,307			$	1,754			$	5,623

As of December 31, 2013 there was $7.4 million of unrecognized compensation costs related to CEI restricted shares for directors, officers and employees. The cost is expected to be recognized over a weighted average period of 1.1 years.
(e) Crosstex Energy, Inc.'s Stock Options
CEI stock options have not been granted since 2005. A summary of the stock option activity includes officers and employees of the Partnership and directors of CEI for the years ended December 31, 2013, 2012 and 2011 is provided below:


		Years Ended December 31,
		2013							2012						2011
		Number of			Weighted				Number of			Weighted			Number of		Weighted
		Units			Average				Units			Average			Units		Average
					Exercise							Exercise					Exercise
					Price							Price					Price
Outstanding, beginning of period		37,500			$	6.5			37,500			$	6.5		37,500		$	6.5

Exercised		(22,500	)		6.5				—			—			—		—

Outstanding, end of period		15,000			$	6.5			37,500			$	6.5		37,500		$	6.5

Options exercisable at end of period		15,000			$	6.5			37,500			$	6.5		37,500		$	6.5

A summary of the stock options intrinsic value exercised (market value in excess of exercise price at date of exercise) and fair value of shares vested (value per Black-Scholes-Merton option pricing model at date of grant) during the years ended December 31, 2013, 2012, and 2011 is provided below (in thousands):


		Years Ended December 31,
Crosstex Energy, Inc. Stock Options:		2013				2012				2011
Intrinsic value of stock options exercised		$	317			$	—			$	—

Fair value of stock options vested		$	—			$	—			$	—

As of December 31, 2013, all options were vested and fully expensed.

Derivatives

Derivatives	12 Months Ended
Derivatives	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivatives	'
	(8) Derivatives
	Commodity Swaps
	The Partnership manages its exposure to fluctuation in commodity prices by hedging the impact of market fluctuations. Swaps are used to manage and hedge price and location risk related to these market exposures. Swaps are also used to manage margins on offsetting fixed-price purchase or sale commitments for physical quantities of natural gas and NGLs.
	The Partnership commonly enters into various derivative financial transactions which it does not designate as hedges. These transactions include "swing swaps," "third party on-system financial swaps," "storage swaps," "basis swaps," "processing margin swaps," "liquids swaps" and "put options." Swing swaps are generally short-term in nature (one month), and are usually entered into to protect against changes in the volume of daily versus first-of-month index priced gas supplies or markets. Third party on-system financial swaps are hedges that the Partnership enters into on behalf of its customers who are connected to its systems, wherein the Partnership fixes a supply or market price for a period of time for its customers and simultaneously enters into the derivative transaction. Storage swap transactions protect against changes in the value of gas that the Partnership has stored to serve various operational requirements. Basis swaps are used to hedge basis location price risk due to buying gas into one of our systems on one index and selling gas off that same system on a different index. Processing margin financial swaps are used to hedge fractionation spread risk at our processing plants relating to the option to process versus bypassing our equity gas. Liquids financial swaps are used to hedge price risk on liquid swaps not otherwise designated as cash flow hedges. Put options are purchased to hedge against declines in pricing and as such represent options, not obligations, to sell the related underlying volumes at a fixed price.
	The components of loss on derivatives in the consolidated statements of operations relating to commodity swaps are (in thousands):


			Years Ended December 31,
			2013				2012				2011
	Change in fair value of derivatives that are not designated for hedge accounting		$	1,674			$	(3,473	)		$	726
			$	1,674			$	(3,473	)		$	726
	Realized losses on derivatives		633				4,514				7,015
	Realized losses on derivatives		633				4,514				7,015
	Ineffective portion of derivatives designated for hedge accounting		(3		)		(35		)		(158		)
	Net losses related to commodity swaps		$	2,304			$	1,006			$	7,583
	Net losses related to commodity swaps		$	2,304			$	1,006			$	7,583
	Put option premium mark to market		—				—				193
	Put option premium mark to market		—				—				193
	Losses on derivatives		$	2,304			$	1,006			$	7,776
	Losses on derivatives		$	2,304			$	1,006			$	7,776
	The fair value of derivative assets and liabilities relating to commodity swaps are as follows (in thousands):


			December 31,
			2013				2012
	Fair value of derivative assets—current, designated		$	9			$	724
	Fair value of derivative assets—current, designated		$	9			$	724
	Fair value of derivative assets—current, non-designated		293				2,510
	Fair value of derivative assets—current, non-designated		293				2,510
	Fair value of derivative assets-long term, non-designated		556				—
	Fair value of derivative assets-long term, non-designated		556				—
	Fair value of derivative liabilities—current, designated		(705		)		(105		)
	Fair value of derivative liabilities—current, non-designated		(463		)		(1,205		)
	Fair value of derivative liabilities—long term, non-designated		(755		)		—
			(755		)		—
	Net fair value of derivatives		$	(1,065	)		$	1,924
	Net fair value of derivatives		$	(1,065	)		$	1,924
	Set forth below is the summarized notional volumes and fair value of all instruments held for price risk management purposes and related physical offsets at December 31, 2013 (all gas volumes are expressed in MMBtus, liquids volumes are expressed in gallons and condensate volumes are expressed in barrels). The remaining term of the contracts extend no later than December 2016. Changes in the fair value of the Partnership's mark to market derivatives are recorded in earnings in the period incurred. The effective portion of changes in the fair value of cash flow hedges is recorded in accumulated other comprehensive income until the related anticipated future cash flow is recognized in earnings. The ineffective portion is recorded in earnings immediately.



			31-Dec-13
	Transaction Type		Volume			Fair Value
			(In thousands)
	Cash Flow Hedges:*
	Liquids swaps (short contracts)		(8,567	)		$	(696	)
	Total swaps designated as cash flow hedges					$	(696	)
	Total swaps designated as cash flow hedges					$	(696	)
	Mark to Market Derivatives:*
	Swing swaps (long contracts)		1,457			$	(14	)
	Swing swaps (long contracts)		1,457			$	(14	)
	Physical offsets to swing swap transactions (short contracts)		(1,147	)		—
			(1,147	)		—
	Swing swaps (short contracts)		(78	)		2
	Swing swaps (short contracts)		(78	)		2
	Physical offsets to swing swap transactions (long contracts)		78			—
			78			—
	Processing margin hedges—liquids (short contracts)		(2,662	)		(270		)
	Processing margin hedges—gas (long contracts)		291			40
	Processing margin hedges—gas (long contracts)		291			40
	Liquids swaps—non-designated (long contracts)		50,400			(537		)
	Liquids swaps—non-designated (long contracts)		50,400			(537		)
	Liquids swaps—non-designated (short contracts)		(50,400	)		428
	Liquids swaps—non-designated (short contracts)		(50,400	)		428
Storage swap transactions (short contracts)		(100	)		(18		)
Total mark to market derivatives					$	(369	)
Total mark to market derivatives					$	(369	)
_______________________________________________________________________________

*	All are gas contracts except for liquids swaps (designated or non-designated), processing margin hedges-liquids and storage swap transactions-condensate inventory.
On all transactions where the Partnership is exposed to counterparty risk, the Partnership analyzes the counterparty's financial condition prior to entering into an agreement, establishes limits and monitors the appropriateness of these limits on an ongoing basis. The Partnership primarily deals with two types of counterparties, financial institutions and other energy companies, when entering into financial derivatives on commodities. The Partnership has entered into Master International Swaps and Derivatives Association Agreements ("ISDAs") that allow for netting of swap contract receivables and payables in the event of default by either party. If the Partnership's counterparties failed to perform under existing swap contracts, the Partnership's maximum loss as of December 31, 2013 of $0.7 million would be reduced to $0.2 million due to the offsetting of gross fair value payables against gross fair value receivables as allowed by the ISDAs.
Impact of Cash Flow Hedges
The impact of realized gains or losses from derivatives designated as cash flow hedge contracts in the consolidated statements of operations is summarized below (in thousands):


		Years Ended December 31,
Increase (decrease) in Midstream revenue		2013				2012				2011
Liquids		$	768			$	1,381			$	(2,772	)
Liquids		$	768			$	1,381			$	(2,772	)
Natural Gas
As of December 31, 2013, the Partnership has no balances in accumulated other comprehensive income (loss) related to natural gas.
Liquids
As of December 31, 2013, an unrealized derivative fair value net loss of $0.7 million related to cash flow hedges of liquids price risk was recorded in accumulated other comprehensive income (loss) all of which is expected to reclassified into earnings by December 2014. The actual reclassification to earnings will be based on mark to market prices at the contract settlement date, along with the realization of the gain or loss on the related physical volume, which amount is not reflected above.
Derivatives Other Than Cash Flow Hedges
Assets and liabilities related to third party derivative contracts, swing swaps, basis swaps, storage swaps, processing margin swaps and liquids swaps are included in the fair value of derivative assets and liabilities and the profit and loss on the mark to market value of these contracts are recorded net as a loss on derivatives in the consolidated statement of operations. The Partnership estimates the fair value of all of its derivatve contracts using actively quoted prices. The estimated fair value of derivative contracts by maturity date was as follows (in thousands):


		Maturity Periods
		Less than				One to				More than				Total
		one year				two years				two years				fair value
December 31, 2013		$	(170	)		$	61			$	(260	)		$	(369	)
December 31, 2013		$	(170	)		$	61			$	(260	)		$	(369	)

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	(9) Fair Value Measurements
	FASB ASC 820 sets forth a framework for measuring fair value and required disclosures about fair value measurements of assets and liabilities. Fair value under FASB ASC 820 is defined as the price at which an asset could be exchanged in a current transaction between knowledgeable, willing parties. A liability's fair value is defined as the amount that would be paid to transfer the liability to a new obligor, not the amount that would be paid to settle the liability with the creditor. Where available, fair value is based on observable market prices or parameters or derived from such prices or parameters. Where observable prices or inputs are not available, use of unobservable prices or inputs are used to estimate the current fair value, often using an internal valuation model. These valuation techniques involve some level of management estimation and judgment, the degree of which is dependent on the item being valued.
	FASB ASC 820 established a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. These tiers include: Level 1, defined as observable inputs such as quoted prices in active markets; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions.
	The Partnership's derivative contracts primarily consist of commodity swap contracts which are not traded on a public exchange. The fair values of commodity swap contracts are determined using discounted cash flow techniques. The techniques incorporate Level 1 and Level 2 inputs for future commodity prices that are readily available in public markets or can be derived from information available in publicly quoted markets. These market inputs are utilized in the discounted cash flow calculation considering the instrument's term, notional amount, discount rate and credit risk and are classified as Level 2 in hierarchy.
	Net assets (liabilities) measured at fair value on a recurring basis are summarized below (in thousands):


			December 31,
			2013			2012
			Level 2			Level 2
	Commodity Swaps*		$	(1,065	)	$	1,924

	Total		$	(1,065	)	$	1,924

	_______________________________________________________________________________

	*	Unrealized gains or losses on commodity derivatives qualifying for hedge accounting are recorded in accumulated other comprehensive income at each measurement date. The fair value of derivative contracts included in assets or liabilities for risk management activities represents the amount at which the instruments could be exchanged in a current arms-length transaction adjusted for credit risk of the Partnership and/or the counterparty as required under FASB ASC 820.
	Fair Value of Financial Instruments
	The estimated fair value of the Company's financial instruments has been determined by the Company using available market information and valuation methodologies. Considerable judgment is required to develop the estimates of fair value, thus, the estimates provided below are not necessarily indicative of the amount the Company could realize upon the sale or refinancing of such financial instruments (in thousands).


			31-Dec-13					31-Dec-12
			Carrying			Fair		Carrying		Fair
			Value			Value		Value		Value
	Long-term debt		$	1,200,472		$	1,281,471	$	1,036,305	$	1,118,875

	Obligations under capital lease		22,036			23,419		25,257		27,667

	The carrying amounts of the Company's cash and cash equivalents, accounts receivable, and accounts payable approximate fair value due to the short-term maturities of these assets and liabilities.
	The Partnership had $155.0 million in borrowings under its revolving credit facility included in long-term debt as of December 31, 2013 and $71.0 million at December 31, 2012. The Subsidiary Borrower had $65.0 million in borrowings under the Subsidiary Credit Agreement included in long-term debt as of December 31, 2013. As borrowings under the Partnership's credit facility, the Subsidiary Credit Agreement and other borrowings related to E2 of $13.2 million accrue interest under a floating interest rate structures, the carrying value of such indebtedness approximates fair value for the amounts outstanding. As of December 31, 2013 and December 31, 2012, the Partnership also had borrowings totaling $717.2 million and $715.3 million, net of discount, respectively, under the 2018 Notes with a fixed rate of 8.875% and borrowings of $250.0 million under the 2022 Notes with a fixed rate of 7.125%. The fair value of all senior unsecured notes as of December 31, 2013 and 2012 was based on Level 1 inputs from third-party market quotations. The fair value of obligations under capital leases was calculated using Level 2 inputs from third-party banks.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitment and Contingencies	'
	(10) Commitments and Contingencies
	*(a) Leases—Lessee*
	The Partnership has operating leases for office space, office and field equipment.
	The following table summarizes the Partnership's remaining non-cancelable future payments under operating leases with initial or remaining non-cancelable lease terms in excess of one year (in thousands):


	2014	$	10,303

	2015	10,338

	2016	8,374

	2017	5,205

	2018	5,771

	Thereafter	15,733

		$	55,724

	Operating lease rental expense in the years ended December 31, 2013, 2012 and 2011 was approximately $28.1 million, $23.2 million and $21.9 million, respectively.
	*(b) Employment and Severance Agreements*
	Certain members of management of the Partnership are parties to employment and/or severance agreements with the general partner. The employment and severance agreements provide those managers with severance payments in certain circumstances and, in the case of employment agreements, prohibit each such person from competing with the general partner or its affiliates for a certain period of time following the termination of such person's employment.
	*(c) Environmental Issues*
	The Partnership acquired LIG Pipeline Company and its subsidiaries on April 1, 2004. Contamination from historical operations was identified during due diligence at a number of sites owned by the acquired companies. The seller, AEP, has indemnified the Partnership for these identified sites. Moreover, AEP has entered into an agreement with a third party company pursuant to which the remediation costs associated with these sites have been assumed by this third party company that specializes in remediation work. To date, 23 of the 25 sites requiring remediation have been completed and have received a "No Further Action" status from the Louisiana Department of Environmental Quality. The remaining two sites continuing with remediation efforts are expected to reach closure in 2014. The Partnership does not expect to incur any material liability with these sites; however, there can be no assurance that the third parties who have assumed responsibility for remediation of site conditions will fulfill their obligations.
	*(d) Other*
	The Company is involved in various litigation and administrative proceedings arising in the normal course of business. In the opinion of management, any liabilities that may result from these claims would not individually or in the aggregate have a material adverse effect on its financial position or results of operations.
	At times, the Partnership's gas-utility and common carrier subsidiaries acquire pipeline easements and other property rights by exercising rights of eminent domain. As a result, the Partnership (or its subsidiaries) is party to a number of lawsuits under which a court will determine the value of pipeline easements or other property interests obtained by the Partnership's gas utility subsidiaries by condemnation. Damage awards in these suits should reflect the value of the property interest acquired and the diminution in the value of the remaining property owned by the landowner. However, some landowners have alleged unique damage theories to inflate their damage claims or assert valuation methodologies that could result in damage awards in excess of the amounts anticipated. Although it is not possible to predict the ultimate outcomes of these matters, the Partnership does not expect that awards in these matters will have a material adverse impact on its consolidated results of operations or financial condition.
	From time to time, owners of property located near the Partnership's processing facilities or compression facilities file lawsuits against the Partnership. These suits generally allege that the facilities create a private nuisance and have damaged the value of surrounding property. Claims of this nature have arisen as a result of the industrial development of natural gas gathering, processing and treating facilities in urban and occupied rural areas. In January 2012, a plaintiff in one of these lawsuits was awarded a judgment of $2.0 million. The Partnership has appealed the matter and has posted a bond to secure the judgment pending its resolution. The Partnership has accrued a $2.0 million liability related to this matter and reflected the related expense in operating expenses in the fourth quarter of 2011. Although it is not possible to predict the ultimate outcomes of these matters, the Partnership does not expect that awards in these matters will have a material adverse impact on its consolidated results of operations or financial condition.
	In July 2013, the Board of Commissioners for the Southeast Louisiana Flood Protection Authority for New Orleans and surrounding areas filed a lawsuit against approximately 100 energy companies, seeking, among other relief, restoration of wetlands allegedly lost due to historic industry operations in those areas. The suit was filed in Louisiana state court in New Orleans, but was removed to federal court. The amount of damages is unspecified. The Partnership's subsidiary, Crosstex LIG, LLC, is one of the named defendants as the owner of pipelines in the area. The validity of the causes of action, as well as the Partnership's costs and legal exposure, if any, related to the lawsuit are not currently determinable. The Partnership intends to vigorously defend the case.

Common_Stock_Notes

Common Stock (Notes)	12 Months Ended
Common Stock (Notes)	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Earnings Per Share [Text Block]	'
	(11) Capital Stock
	(a) Common Stock
	In October 2006, the Company's stockholders approved an increase in the number of authorized shares of capital stock from 20 million shares, consisting of 19 million shares of common stock and 1 million shares of preferred stock, to 150 million shares, consisting of 140 million shares of common stock and 10 million shares of preferred stock.
	(b) Earnings per Share and Anti-Dilutive Computations
	Basic earnings per common share was computed by dividing net income by the weighted-average number of common shares outstanding for the periods presented. The computation of diluted earnings per common share further assumes the dilutive effect of common share options and restricted shares. All common share equivalents were antidilutive for the years ended December 31, 2013, 2012 and 2011 because the Company had net losses in these periods.
	The Company has issued restricted shares that entitle employees to receive non-forfeitable dividends during their vesting period and are therefore considered participating securities for earnings per share calculations. The restricted shares, which participate in earnings and dividends in the same manner as other common shares, were allocated a total net loss of $961,000, $307,000 and $125,000 for the years ended December 31, 2013, 2012 and 2011, respectively.

Segment_Information

Segment Information	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segment Information	'
	(12) Segment Information
	Identification of operating segments is based principally upon regions served. The Partnership's reportable segments consist of the natural gas gathering, processing and transmission operations located in north Texas and in the Permian Basin in west Texas ("NTX"), the pipelines and processing plants located in Louisiana ("LIG"), the south Louisiana processing and NGL assets ("PNGL") and rail, truck, pipeline, and barge facilities in the Ohio River Valley ("ORV"), which includes the Company's investment in E2. The Partnership's sales are derived from external domestic customers.
	The Partnership evaluates the performance of its operating segments based on operating revenues and segment profits. Corporate expenses include general partnership expenses associated with managing all reportable operating segments. Corporate assets consist principally of property and equipment, including software, for general corporate support, working capital, debt financing costs and its investment in HEP. Profit in the corporate segment for the years ended 2013 and 2012 includes the operating activity for intersegment eliminations.
	Summarized financial information concerning the Partnership's reportable segments is shown in the following table.


			LIG				NTX				PNGL				ORV				Corporate				Totals
			(In thousands)
	Year Ended December 31, 2013:
	Sales to external customers		$	491,217			$	321,025			$	850,245			$	281,825			$	—			$	1,944,312

	Sales to affiliates		89,081				72,960				22,144				—				(184,185		)		—

	Purchased gas, NGLs, condensate and crude oil		(495,807		)		(229,687		)		(777,989		)		(227,689		)		184,185				(1,546,987		)

	Operating expenses		(31,699		)		(53,772		)		(30,735		)		(34,652		)		—				(150,858		)

	Segment profit		$	52,792			$	110,526			$	63,665			$	19,484			$	—			$	246,467

	Gain (loss) on derivatives		$	92			$	(1,768	)		$	(289	)		$	(339	)		$	—			$	(2,304	)

	Depreciation, amortization and impairments		$	(12,706	)		$	(79,303	)		$	(106,412	)		$	(11,591	)		$	(2,849	)		$	(212,861	)
	Capital expenditures		$	45,569			$	23,175			$	394,514			$	99,127			$	4,465			$	566,850

	Identifiable assets		$	301,431			$	991,332			$	1,003,596			$	407,121			$	145,347			$	2,848,827

	Year Ended December 31, 2012:

	Sales to external customers		$	561,389			$	269,302			$	852,560			$	108,037			$	—			$	1,791,288

	Sales to affiliates		225,542				96,177				145,569				—				(467,288		)		$	—

	Purchased gas, NGLs, condensate and crude oil		(678,188		)		(180,116		)		(924,240		)		(82,274		)		467,288				(1,397,530		)

	Operating expenses		(33,817		)		(55,582		)		(29,601		)		(11,882		)		—				$	(130,882	)

	Segment profit		$	74,926			$	129,781			$	44,288			$	13,881			$	—			$	262,876

	Gain (loss) on derivatives		$	3,440			$	(4,405	)		$	(41	)		$	—			$	—			$	(1,006	)

	Depreciation, amortization and impairments		$	(13,936	)		$	(83,492	)		$	(57,652	)		$	(4,861	)		$	(2,359	)		$	(162,300	)
	Capital expenditures		$	4,059			$	45,235			$	182,782			$	3,893			$	8,944			$	244,913

	Identifiable assets		$	279,755			$	1,057,504			$	632,962			$	316,927			$	139,327			$	2,426,475

	Year Ended December 31, 2011:

	Sales to external customers		$	811,216			$	332,026			$	870,700			$	—			$	—			$	2,013,942

	Sales to affiliates		128,130				100,527				40,185				—				(268,842		)		—

	Purchased gas, NGLs, condensate and crude oil		(809,471		)		(262,708		)		(835,440		)		—				268,842				(1,638,777		)

	Operating expenses		(35,434		)		(48,807		)		(27,537		)		—				—				(111,778		)

	Segment profit		$	94,441			$	121,038			$	47,908			$	—			$	—			$	263,387

	Gain (loss) on derivatives		$	(6,145	)		$	(1,896	)		$	265			$	—			$	—			$	(7,776	)

	Depreciation, amortization and impairments		$	(13,676	)		$	(76,535	)		$	(31,271	)		$	—			$	(3,876	)		$	(125,358	)

	Capital expenditures		$	2,820			$	73,069			$	25,618			$	—			$	2,629			$	104,136

Identifiable assets		$	305,359			$	1,113,431			$	460,865			$	—			$	82,961			$	1,962,616

The following table reconciles the segment profits reported above to the operating income as reported in the consolidated statements of operations (in thousands):


		Years Ended December 31,
		2013				2012				2011
Segment profits		$	246,467			$	262,876			$	263,387

General and administrative expenses		(79,993		)		(65,083		)		(55,516		)
Loss on derivatives		(2,304		)		(1,006		)		(7,776		)
Gain (loss) on sale of property		1,055				342				(264		)

Depreciation, amortization and impairments		(212,861		)		(162,300		)		(125,358		)
Operating income (loss)		$	(47,636	)		$	34,829			$	74,473

Immaterial_Correction_of_Prior

Immaterial Correction of Prior Period Financial Statements	12 Months Ended
	Dec. 31, 2013
Accounting Changes and Error Corrections [Abstract]	'
Immaterial Correction of Prior Period Financial Statements	'
	(13) Immaterial Correction of Prior Period Financial Statements

	During the year ended December 31, 2013, the Company determined certain immaterial corrections were required for previously-issued financial statements for the year ended December 31, 2012, as discussed below. The corrections did not impact the Company’s operating income and were not considered material to the Company’s revenues and costs for the applicable periods.

	The Company determined that revenues and purchased gas costs related to a new processing arrangement were improperly reduced from revenue and purchased gas costs which resulted in equal understatements of revenues and purchased gas costs in its previously-issued financial statements for the year ended December 31, 2012. As a result both revenues and purchased gas were understated by $135.4 million for the year ended December 31, 2012. The following table reflects the revenues, purchased gas costs and total operating costs and expenses as previously reported and as adjusted for the year ended December 31, 2012 (in thousands):


	As previously reported:	Year Ended December 31, 2012
	Total revenues	$	1,655,851

	Purchased gas, NGLs, condensate and crude oil	$	1,262,093

	Total operating costs and expenses	$	1,621,022

	Operating income	$	34,829


	As adjusted:
	Total revenues	$	1,791,288

	Purchased gas, NGLs, condensate and crude oil	$	1,397,530

	Total operating costs and expenses	$	1,756,459

	Operating income	$	34,829

Quarterly_Financial_Data_Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Quarterly Financial Data	'
	(14) Quarterly Financial Data (Unaudited)
	Summarized unaudited quarterly financial data is presented below.


		First			Second			Third			Fourth			Total
		(In thousands, except per share data)
	2013:00:00
	Revenues	$	445,689		$	454,737		$	468,643		$	575,243		$	1,944,312

	Operating income (loss)	$	14,130		$	5,878		$	(62,833	)	$	(4,811	)	$	(47,636	)

	Net loss attributable to the noncontrolling interest	$	(2,168	)	$	(6,744	)	$	(61,617	)	$	(12,470	)	$	(82,999	)
	Net loss attributable to the Crosstex Energy, Inc	$	(2,936	)	$	(4,667	)	$	(11,249	)	$	(10,784	)	$	(29,636	)
	Basic earnings per common share	$	(0.06	)	$	(0.09	)	$	(0.23	)	$	(0.22	)	$	(0.60	)
	Diluted earnings per common share	$	(0.06	)	$	(0.09	)	$	(0.23	)	$	(0.22	)	$	(0.60	)
	2012:00:00
	Revenues	$	425,959		$	394,402		$	444,947		$	525,980		$	1,791,288

	Operating income (loss)	$	22,074		$	18,381		$	899		$	(6,525	)	$	34,829

	Net income (loss) attributable to the noncontrolling interest	$	3,594		$	(530	)	$	(10,240	)	$	(17,083	)	$	(24,259	)

	Net loss attributable to the Crosstex Energy, Inc.	$	(825	)	$	(1,672	)	$	(4,314	)	$	(5,670	)	$	(12,481	)
	Basic earnings per common share	$	(0.02	)	$	(0.03	)	$	(0.09	)	$	(0.12	)	$	(0.26	)
	Diluted earnings per common share	$	(0.02	)	$	(0.03	)	$	(0.09	)	$	(0.12	)	$	(0.26	)

Subsequent_Events

Subsequent Events	12 Months Ended
Subsequent Events	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events [Text Block]	'
	(15) Subsequent Events
	2022 Notes. On January 3, 2014, the Partnership instructed the trustee to deliver a notice of redemption for approximately $53.5 million in aggregate principal amount of its 2022 Notes (the “Redeemed Notes”), representing approximately 21% of the aggregate principal amount of the outstanding 2022 Notes. The Redeemed Notes were redeemed effective as of February 2, 2014 for a total redemption price equal to $1,083.32 per $1,000 principal amount redeemed. Following the completion of the redemption, approximately $196.5 million aggregate principal amount of the 2022 Notes remain outstanding.

	Credit Facility. On February 20, 2014, the Partnership entered into a $1.0 billion unsecured revolving credit facility, which includes a $500.0 million letter of credit subfacility (the “new credit facility”). The Partnership's ability to borrow funds and obtain letters of credit under the new credit facility is conditioned upon, among other things. the closing of the Contribution and the prior or concurrent termination of the Partnership’s existing credit facility. Upon the termination of the existing credit facility, the liens securing the existing credit facility will be released and the Partnership’s subsidiaries will no longer guarantee its indebtedness and will be released as guarantors under the indentures governing the Partnership’s Senior Notes.
	The new credit facility will mature on the fifth anniversary of the initial funding date, unless the Partnership requests, and the requisite lenders agree, to extend it pursuant to its terms. The new credit facility contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of consolidated indebtedness to consolidated EBITDA (as defined in the new credit facility, which definition includes projected EBITDA from certain capital expansion projects) of no more than 5.0 to 1.0. If the Partnership consummates one or more acquisitions in which the aggregate purchase price is $50.0 million or more, the maximum allowed ratio of consolidated indebtedness to consolidated EBITDA will increase to 5.5 to 1.0 for the quarter of the acquisition and the three following quarters.
	Borrowings under the new credit facility bear interest at the Partnership’s option at the Eurodollar Rate (the LIBOR Rate) plus an applicable margin or the Base Rate (the highest of the Federal Funds Rate plus 0.50%, the 30-day Eurodollar Rate plus 1.0%, or the administrative agent’s prime rate) plus an applicable margin. The applicable margins vary depending on the Partnership's credit rating. Upon breach by the Partnership of certain covenants governing the new credit facility, amounts outstanding under the new credit facility, if any, may become due and payable immediately.

Condensed_Financial_Informatio

Condensed Financial Information of Parent Company (Notes)	12 Months Ended
	Dec. 31, 2013
Condensed Financial Information of Parent Company Only [Abstract]	'
Condensed Financial Information of Parent Company Only Disclosure [Text Block]	'
	CROSSTEX ENERGY, INC. (PARENT COMPANY)
	CONDENSED BALANCE SHEETS


			December 31,
			2013				2012
			(In thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents		$	1,764			$	2,852

	Accounts receivable		633				—

	Prepaid expenses and other		483				120

	Total current assets		2,880				2,972

	Property and equipment:
	Gathering systems		3,614				—

	Construction in process		79,241				—

	Accumulated depreciation		(160		)		—

	Total property and equipment, net		82,695				—

	Intangibles		4,246				—

	Investment in the Partnership		199,885				217,425

	Other assets, net		1,112				—

	Total assets		$	290,818			$	220,397

	LIABILITIES AND STOCKHOLDERS' EQUITY
	Current liabilities:
	Accounts payable		$	6,168			$	—

	Related party payable		2,569				—

	Other current liabilities		1,153				580

	Total current liabilities		9,890				580

	Long term debt		78,270				—

	Deferred tax liability		56,733				62,151

	Other long term liabilities		47				—

	Stockholders' equity:
	Common stock		476				473

	Additional paid-in capital		307,835				274,635

	Accumulated deficit		(171,263		)		(117,583		)
	Accumulated other comprehensive loss		(58		)		141

	Stockholders' equity		136,990				157,666

	Non-controlling interest		8,888				—

	Total stockholders' equity		145,878				157,666

Total liabilities and stockholders' equity		$	290,818			$	220,397

CROSSTEX ENERGY, INC. (PARENT COMPANY)
CONDENSED STATEMENTS OF OPERATIONS




		Years ended December 31,
		2013				2012				2011
		(In thousands, except per share data)
Revenues:
Midstream		$	1,073			$	—			$	—

Total revenues		1,073				—				—

Operating costs and expenses:
Loss from investment in the Partnership		30,400				16,080				7,192

Operating expenses		513				—				—

General and administrative expenses		11,932				3,775				2,715

Depreciation and amortization		185				—				—

Total operating costs and expenses		43,030				19,855				9,907

Operating loss		(41,957		)		(19,855		)		(9,907		)
Other income (expense):
Interest and other income		(407		)		7				6

Loss before income taxes		(42,364		)		(19,848		)		(9,901		)
Income tax benefit		12,551				7,367				3,894

Net loss		(29,813		)		(12,481		)		(6,007		)
Less: Net loss attributable to the noncontrolling interest		(177		)		—				—

Net loss attributable to Crosstex Energy, Inc.		$	(29,636	)		$	(12,481	)		$	(6,007	)
Net loss per common share:
Basic		$	(0.60	)		$	(0.26	)		$	(0.12	)
Diluted		$	(0.60	)		$	(0.26	)		$	(0.12	)
Weighted average common shares outstanding:
Basic		$	47,664			$	47,384			$	47,150

Diluted		$	47,664			$	47,384			$	47,150

CROSSTEX ENERGY, INC. (PARENT COMPANY)
CONDENSED STATEMENTS OF CASH FLOWS


		Years Ended December 31,
		2013				2012				2011
		(In thousands)
Cash flows from operating activities:
Net loss		$	(29,636	)		$	(12,481	)		$	(6,007	)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization		185				—				—

Loss from investment in the Partnership		30,400				16,080				7,196

Deferred tax benefit		(12,551		)		(7,367		)		(3,896		)
Stock-based compensation		212				277				249

Interest paid in kind		1,766				—				—

Amortization of debt issue cost		343				—				—

Changes in assets and liabilities:
Accounts receivable, prepaid expenses and other		(1,017		)		(27		)		(57		)
Accounts payable, and other accrued liabilities		3,222				79				238

Net cash used in operating activities		(7,076		)		(3,439		)		(2,277		)
Cash flows from investing activities:
Additions to property and equipment		(76,649		)		—				—

Investment in the Partnership		—				(3,460		)		(163		)

Distributions from the Partnership		28,936				27,270				22,497

Net cash provided by investing activities		(47,713		)		23,810				22,334

Cash flows from financing activities:
Proceeds from borrowings		77,737				—				—

Payments on borrowings		(1,233		)		—				—

Debt refinancing cost		(1,460		)		—				—

Conversion of restricted stocks, net of stocks withheld for taxes		(2,087		)		(794		)		(1,068		)
Contributions from non-controlling partners		4,642				—				—

Common dividends paid		(24,044		)		(22,925		)		(17,872		)
Proceeds from exercise of share options		146				—				—

Net cash provided by (used in) financing activities		53,701				(23,719		)		(18,940		)

Net increase (decrease) in cash and cash equivalents		(1,088		)		(3,348		)		1,117

Cash, beginning of period		2,852				6,200				5,083

Cash, end of period		$	1,764			$	2,852			$	6,200

Non-cash transactions:
Gain from issuance of Partnership units		$	35,123			$	15,890			$	—

Stock-based compensation attributed to CEI for its restricted stock granted to Partnership officers, employees and directors		$	7,000			$	4,200			$	3,100

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Policy Text Block [Abstract]	'
Use of Estimates	'
	(a) Management's Use of Estimates
	The preparation of financial statements in accordance with accounting principles generally accepted in the United States of America requires management of the Company to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the period. Actual results could differ from these estimates.
Cash and Cash Equivalents	'
	(b) Cash and Cash Equivalents
	The Company considers all highly liquid investments with an original maturity of three months or less to be cash equivalents.
Natural Gas and Natural Gas Liquids Inventory	'
	(c) Natural Gas, Natural Gas Liquids, Crude Oil and Condensate Inventory
	Inventories of products consist of natural gas, NGLs, crude oil and condensate. The Company reports these assets at the lower of cost or market.
Property, Plant, and Equipment	'
	(d) Property, Plant, and Equipment
	Property, plant and equipment consist of intrastate gas transmission systems, gas gathering systems, NGL, condensate and crude oil pipelines, natural gas processing plants, NGL fractionation plants and brine disposal wells. Gas required to maintain pipeline minimum pressures is capitalized and classified as property, plant and equipment. Other property and equipment is primarily comprised of the ORV trucking fleet, computer software and equipment, furniture, fixtures, leasehold improvements and office equipment. Property, plant and equipment are recorded at cost. Repairs and maintenance are charged against income when incurred. Renewals and betterments, which extend the useful life of the properties, are capitalized. Interest costs are capitalized to property, plant and equipment during the period the assets are undergoing preparation for intended use. Interest costs totaling $24.5 million, $4.0 million and $0.9 million were capitalized for the years ended December 31, 2013, 2012 and 2011, respectively.
	Depreciation is calculated using the straight-line method based on the estimated useful life of each asset, as follows:


			Useful Lives
	Transmission assets		20 - 30 years
	Gathering systems		15 - 20 years
	Gas processing plants		20 years
	Other property and equipment		3 - 15 years
	Depreciation expense of $99.8 million, $98.2 million and $77.8 million was recorded for the years ended December 31, 2013, 2012 and 2011, respectively. Depreciation expense also includes the amortization of assets classified as capital lease assets.
Goodwill and Intangible Assets	'
	(e) Goodwill and Intangible Assets
	Goodwill is the cost of an acquisition less the fair value of the net identifiable assets of the acquired business. The Partnership evaluates goodwill for impairment annually as of July 1, 2013, and whenever events or changes in circumstances indicate it is more likely than not that the fair value of a reporting unit is less than its carrying amount. The Partnership first assesses qualitative factors to evaluate whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as the basis for determining whether it is necessary to perform the two-step goodwill impairment test. The Partnership may elect to perform the two-step goodwill impairment test without completing a qualitative assessment. If a two-step process goodwill impairment test is elected or required, the first step involves comparing the fair value of the reporting unit, to which goodwill has been allocated, with its carrying amount. If the carrying amount of a reporting unit exceeds its fair value, the second step of the process involves comparing the implied fair value to the carrying value of the goodwill for that reporting unit. If the carrying value of the goodwill of a reporting unit exceeds the implied fair value of that goodwill, the excess of the carrying value over the implied fair value is recognized as an impairment loss.
	The Partnership has approximately $153.8 million and $152.6 million of goodwill at December 31, 2013 and 2012, respectively, related to the acquisition of Clearfield Energy, Inc. and its wholly-owned subsidiaries (collectively, "Clearfield") in July 2012. The goodwill recognized from the Clearfield acquisition results primarily from the value of opportunity created from the strategic asset positioning in the Utica and Marcellus shale plays which provides the Partnership with a substantial growth platform in a new geographic area. The goodwill is allocated to the ORV segment. There were no impairment charges resulting from the Partnership's July 1, 2013 impairment testing, and no event indicating impairment has occurred subsequent to that date.
	Intangible assets consist of customer relationships and the value of the dedicated and non-dedicated acreage attributable to pipeline, gathering and processing systems. Intangible assets associated with customer relationships are amortized on a straight-line basis over the expected period of benefits of the customer relationships, which range from three to twenty years. The intangible assets associated with dedicated and non-dedicated acreage attributable to pipeline, gathering and processing systems are being amortized using the units of throughput method of amortization.
	The following table represents the Partnership's total purchased intangible assets at years ended December 31, 2013 and 2012 (in thousands)


			Gross		Accumulated			Net
			Carrying		Amortization			Carrying
			Amount					Amount
	2013
	Customer relationships (1)		$	148,456	$	(65,125	)	$	83,331

	Dedicated and non-dedicated acreage		395,649		(162,758		)	232,891

	Total		$	544,105	$	(227,883	)	$	316,222

	2012
	Customer relationships		$	292,658	$	(130,458	)	$	162,200

	Dedicated and non-dedicated acreage		395,652		(132,847		)	262,805

	Total		$	688,310	$	(263,305	)	$	425,005

	(1) See Note 4-"Acquisition, Disposition and Impairments" for information related to an impairment on the Partnership's Eunice customer relationships in 2013.

	The weighted average amortization period for intangible assets is 19.0 years. Amortization expense for intangibles was approximately $40.5 million, $64.1 million and $47.5 million for the years ended December 31, 2013 , 2012 and 2011, respectively.
	The following table summarizes the Partnership's estimated aggregate amortization expense for the next five years (in thousands):


	2014	$	35,827

	2015	34,430

	2016	32,944

	2017	32,269

	2018	31,882

	Thereafter	148,870

	Total	$	316,222

Investment in Limited Liability Company	'
	(f) Investment in Limited Liability Company
	On June 22, 2011, the Partnership entered into a limited liability agreement with Howard Energy Partners ("HEP") for an initial capital contribution of $35.0 million in exchange for an individual ownership interest in HEP. In 2013 and 2012, the Partnership made additional capital contributions of $30.6 million and $52.3 million, respectively. Additionally, the Partnership received a distributions of $17.5 million in 2013. HEP owns midstream assets and provides midstream services to Eagle Ford Shale producers. The Partnership owns 30.6 percent of HEP and accounts for this investment under the equity method of accounting. In December 2013, Alinda Capital Partners acquired a 59% capital interest in HEP from Quanta Capital Solutions and GE Energy Financial Services. This investment is reflected on the balance sheet as "Investment in limited liability company." The Partnership's proportional share of earnings is recorded as an increase to this investment account and recorded as equity in income of limited liability company.
Joint Venture Investment	'
	(g) Investment in E2

	In March 2013, the Company entered into an agreement to form E2 Energy Services, LLC and E2 Appalachian Compression, LLC ("E2"), which are companies that provide compression and stabilization services for producers in the liquids-rich window of the Utica Shale play. The Company owns approximately 93.7% of E2 Energy Services, LLC and a 92.5% interest in E2 Appalachian Compression, LLC and has pre-determined rights to purchase the management ownership interests of E2 in the future. The Company owns a majority interest in E2 and consolidates its investment in E2 pursuant to Financial Accounting Standards Board ("FASB") ASC 810-10-05-08. The Company has committed to invest of approximately $76.0 million in E2 to fund the construction of three new natural gas compression and condensate stabilization facilities, which E2 will own and operate. The facilities are located in Noble and Monroe counties in the southern portion of the Utica Shale play in Ohio. As of December 31, 2013, the Company has invested $60.7 million in E2. Commercial operations of the first facility began during the first quarter of 2014 and the remaining plants are expected to be operational during the first half of 2014.
Other Assets	'
	(h) Other Assets
	Unamortized debt issuance costs totaling $22.8 million and $26.0 million as of December 31, 2013 and 2012, respectively, are included in other assets, net. Debt issuance costs are amortized into interest expense using the straight-line method over the term of the debt.
Gas Imbalance Accounting	'
	(i) Gas Imbalance Accounting
	Quantities of natural gas and NGLs over-delivered or under-delivered related to imbalance agreements are recorded monthly as receivables or payables using weighted average prices at the time of the imbalance. These imbalances are typically settled with deliveries of natural gas or NGLs. The Company had imbalance payables of $4.8 million and $2.3 million at December 31, 2013 and 2012, respectively, which approximate the fair value of these imbalances. The Company had imbalance receivables of $4.2 million and $1.5 million at December 31, 2013 and 2012, respectively, which are carried at the lower of cost or market value.
Asset Retirement Obligations	'
	(j) Asset Retirement Obligations
	FASB ASC 410-20-25-16 was issued in March 2005 and became effective at December 31, 2005. FASB ASC 410-20-25-16 clarifies that the term "conditional asset retirement obligation" as used in FASB ASC 410-20, refers to a legal obligation to perform an asset retirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity. Since the obligation to perform the asset retirement activity is unconditional, FASB ASC 410-20-25-16 provides that a liability for the fair value of a conditional asset retirement activity should be recognized if that fair value can be reasonably estimated, even though uncertainty exists about the timing and/or method of settlement. FASB ASC 410-20-25-16 also clarifies when an entity would have sufficient information to reasonably estimate the fair value of an asset retirement obligation under FASB ASC 410-20. The Company provided an asset retirement obligation of $0.5 million and $0.5 million as of December 31, 2013 and 2012, respectively,
Revenue Recognition	'
	(k) Revenue Recognition
	The Company recognizes revenue for sales or services at the time the natural gas, NGLs, condensate or crude oil are delivered or at the time the service is performed. The Company generally accrues one month of sales and the related gas, condensate and crude oil purchases and reverses these accruals when the sales and purchases are actually invoiced and recorded in the subsequent months. Actual results could differ from the accrual estimates. Purchase and sale arrangements are generally reported in revenues and costs on a gross basis in the consolidated statement of operations in accordance with FASB ASC 605-45-45-1. Except for fee based arrangements, the Partnership acts as the principal in these purchase and sale transactions, has the risk and reward of ownership as evidenced by title transfer, schedules the transportation and assumes credit risk. The Partnership conducts "off-system" gas marketing operations as a service to producers on systems that it does not own. It refers to these activities as part of energy trading activities. In some cases, the Partnership earns an agency fee from the producer for arranging the marketing of the producer's natural gas. In other cases, the Partnership purchases the natural gas from the producer and enters into a sales contract with another party to sell the natural gas. The revenue and cost of sales for these activities are included in revenue on a net basis in the consolidated statement of operations.
	The Company accounts for taxes collected from customers attributable to revenue transactions and remitted to government authorities on a net basis (excluded from revenues).
Derivatives	'
	Derivatives
	The Partnership uses derivatives to hedge against changes in cash flows related to product price, as opposed to their use for trading purposes. FASB ASC 815 requires that all derivatives be recorded on the balance sheet at fair value. It generally determines the fair value of futures contracts and swap contracts based on the difference between the derivative's fixed contract price and the underlying market price at the determination date. The asset or liability related to the derivative instruments is recorded on the balance sheet in fair value of derivative assets or liabilities.
	Realized and unrealized gains and losses on commodity related derivatives that are not designated as hedges, as well as the ineffective portion of hedge derivatives, are recorded as gain or loss on derivatives in the consolidated statement of operations in the period incurred. Unrealized gains and losses on effective cash flow hedge derivatives are recorded as a component of accumulated other comprehensive income. When the hedged transaction occurs, the realized gain or loss on the hedge derivative is transferred from accumulated other comprehensive income to earnings. Realized gains and losses on commodity hedge derivatives are recognized in revenues. Settlements of derivatives are included in cash flows from operating activities.
Comprehensive Income, Policy	'
	(l) Comprehensive Income (Loss)
	Comprehensive income includes net income (loss) and other comprehensive income, which includes unrealized gains and losses on derivative financial instruments. Pursuant to FASB ASC 815, the Company records deferred hedge gains and losses on its derivative financial instruments that qualify as cash flow hedges as other comprehensive income.
	In February 2013, the FASB issued ASU 2013-2, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income ("ASU 2013-2”). ASU 2013-2 requires disclosure of amounts reclassified out of accumulated other comprehensive income ("AOCI") by component. In addition, an entity is required to present, either on the face of the statement where net income is presented or in the notes, significant amounts reclassified out of AOCI by the respective line items of net income but only if the amount reclassified is required to be reclassified to net income in its entirety in the same reporting period. For amounts not reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures that provide additional detail about those amounts. For the years ended December 31, 2013, 2012 and 2011, we reclassified cash flow hedge (gains) losses in the amounts of $(1.0) million, $(0.6) million and $1.8 million, respectively, included in other comprehensive income to revenues on the consolidated statements of operations.
Legal Costs Expected to be Incurred	'
	Legal Costs Expected to be Incurred in Connection with a Loss Contingency
	Legal costs incurred in connection with a loss contingency are expensed as incurred.
Concentrations of Credit Risk	'
	(n) Concentrations of Credit Risk
	Financial instruments, which potentially subject the Partnership to concentrations of credit risk, consist primarily of trade accounts receivable and derivative financial instruments. Management believes the risk is limited since the Partnership's customers represent a broad and diverse group of energy marketers and end users. In addition, the Partnership continually monitors and reviews credit exposure to its marketing counter-parties and letters of credit or other appropriate security are obtained as considered necessary to limit the risk of loss. The Partnership's records reserves for uncollectible accounts on a specific identification basis since there is not a large volume of late paying customers. The Partnership had a reserve for uncollectible receivables as of December 31, 2013 and 2012 of $0.6 million and $0.5 million, respectively.
	During the years ended December 31, 2013, 2012, and 2011, the Partnership had only one customer that individually represented greater than 10.0% of its revenues. The customer is located in the LIG segment and represented 12.6%, 10.5% and 12.3% of consolidated revenue for each of the years ended December 31, 2013, 2012 and 2011, respectively.
Environmental Costs	'
	(p) Environmental Costs
	Environmental expenditures are expensed or capitalized as appropriate, depending on the nature of the expenditures and their future economic benefit. Expenditures that related to an existing condition caused by past operations that do not contribute to current or future revenue generation are expensed. Liabilities for these expenditures are recorded on an undiscounted basis (or a discounted basis when the obligation can be settled at fixed and determinable amounts) when environmental assessments or clean-ups are probable and the costs can be reasonably estimated. For the years ended December 31, 2013, 2012 and 2011, such expenditures were not significant.
Share-Based Awards	'
	(q) Share-Based Awards
	The Company recognizes compensation cost related to all stock-based awards, including stock options, in its consolidated financial statements in accordance with FASB ASC 718. The Partnership and CEI each have similar unit or share-based payment plans for employees, which are described below. Share-based compensation associated with CEI's share-based compensation plans awarded to officers and employees of the general partner of the Partnership are recorded by the Partnership since CEI has no substantial or managed operating activities other than its interest in the Partnership. Amounts recognized in the consolidated financial statements with respect to these plans are as follows (in thousands):


			Years Ended December 31,
			2013		2012			2011
	Cost of share-based compensation charged to general and administrative expense		$	12,546	$	8,240		$	6,405

	Cost of share-based compensation charged to operating expense		1,837		1,243			1,151

	Total amount charged to income		$	14,383	$	9,483		$	7,556

	Interest of non-controlling partners in share-based compensation		$	5,656	$	3,813		$	3,052

	Amount of related income tax benefit recognized in income		$	3,235	$	2,102		$	1,670

Recent Accounting Pronouncements	'
	(r) Recent Accounting Pronouncements
	We have reviewed all recently issued accounting pronouncements that became effective during the year ended December 31, 2013, and have determined that none would have a material impact on our Consolidated Financial Statements.

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Policy Text Block [Abstract]	'
Schedule Of Property Plant And Equipment Useful Lives [Table Text Block]	'
	Depreciation is calculated using the straight-line method based on the estimated useful life of each asset, as follows:


			Useful Lives
	Transmission assets		20 - 30 years
	Gathering systems		15 - 20 years
	Gas processing plants		20 years
	Other property and equipment		3 - 15 years
Schedule of Finite-Lived Intangible Assets [Table Text Block]	'
	The following table represents the Partnership's total purchased intangible assets at years ended December 31, 2013 and 2012 (in thousands)


			Gross		Accumulated			Net
			Carrying		Amortization			Carrying
			Amount					Amount
	2013
	Customer relationships (1)		$	148,456	$	(65,125	)	$	83,331

	Dedicated and non-dedicated acreage		395,649		(162,758		)	232,891

	Total		$	544,105	$	(227,883	)	$	316,222

	2012
	Customer relationships		$	292,658	$	(130,458	)	$	162,200

	Dedicated and non-dedicated acreage		395,652		(132,847		)	262,805

	Total		$	688,310	$	(263,305	)	$	425,005

Schedule of Finite-Lived Intangible Assets, Future Amortization Expense [Table Text Block]	'
	The following table summarizes the Partnership's estimated aggregate amortization expense for the next five years (in thousands):


	2014	$	35,827

	2015	34,430

	2016	32,944

	2017	32,269

	2018	31,882

	Thereafter	148,870

	Total	$	316,222

Schedule of Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Table Text Block]	'
	Amounts recognized in the consolidated financial statements with respect to these plans are as follows (in thousands):


			Years Ended December 31,
			2013		2012			2011
	Cost of share-based compensation charged to general and administrative expense		$	12,546	$	8,240		$	6,405

	Cost of share-based compensation charged to operating expense		1,837		1,243			1,151

	Total amount charged to income		$	14,383	$	9,483		$	7,556

	Interest of non-controlling partners in share-based compensation		$	5,656	$	3,813		$	3,052

	Amount of related income tax benefit recognized in income		$	3,235	$	2,102		$	1,670

Public_Offering_of_Units_and_C1

Public Offering of Units and Certain Provisions of the Partnership Agreement General Partner Share of Net Income (Tables)	12 Months Ended
	Dec. 31, 2013
Partners' Capital Notes [Abstract]	'
Schedule of Incentive Distributions Made to Managing Members or General Partners by Distribution [Table Text Block]	'
	The following table reflects the Company's general partner share of the Partnership's net income (loss) (in thousands):



		Years Ended December 31,
		2013			2012			2011
	Income allocation for incentive distributions	$	6,390		$	4,489		$	2,372

	Stock-based compensation attributable to CEI's restricted shares	(6,973		)	(4,205		)	(3,119		)
	General partner interest in net income (loss)	(2,138		)	(818		)	15

	General partner share of net loss	$	(2,721	)	$	(534	)	$	(732	)

Acquisitions_Disposition_and_I1

Acquisitions, Disposition and Impairments (Table)	12 Months Ended
Acquisitions, Disposition and Impairments (Table)	Dec. 31, 2013
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net [Abstract]	'
Purchase Price Allocation	'
	following table is a summary of the consideration paid in the Clearfield acquisition and the purchase price allocation for the fair value of the assets acquired and liabilities assumed at the acquisition date,:


	Purchase Price Allocation (in thousands):
	Purchase Price to Clearfield Energy, Inc.	$	215,397
	Purchase Price to Clearfield Energy, Inc.	$	215,397
	Total purchase price	$	215,397
	Total purchase price	$	215,397
	Assets acquired:
	Current assets	$	17,622
	Current assets	$	17,622
	Assets held for disposition	19,358
	Assets held for disposition	19,358
	Property, plant, and equipment	91,422
	Property, plant, and equipment	91,422
	Goodwill	153,802
	Goodwill	153,802
	Intangibles	37,600
	Intangibles	37,600
	Liabilities assumed:
	Current liabilities	(28,274		)
	Liabilities held for disposition	(1,400		)
	Deferred taxes	(65,228		)
	Long term liabilities	(9,505		)
	Total purchase price	$	215,397
	Total purchase price	$	215,397
Pro Forma	'
	The following unaudited pro forma condensed financial data for the year ended December 31, 2012 and 2011 gives effect to the Clearfield acquisition as if it had occurred on January 1, 2011. The unaudited pro forma condensed financial information has been included for comparative purposes only and is not necessarily indicative of the results that might have occurred had the transactions taken place on the dates indicated and is not intended to be a projection of future results.


			Year Ended
			31-Dec-12			31-Dec-11
			(in thousands except for per unit data)
	Pro forma total revenues		$	1,897,199		$	2,266,868
	Pro forma total revenues		$	1,897,199		$	2,266,868
	Pro forma net loss		$	(39,021	)	$	(15,476	)
	Pro forma net loss attributable to Crosstex Energy, Inc.		$	(14,762	)	$	(8,460	)
	Pro forma net loss per common unit:
	Basic and Diluted		$	(0.30	)	$	(0.18	)

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Indebtedness Table	'
	As of December 31, 2013 and 2012, long-term debt consisted of the following (in thousands):


			2013			2012
	Partnership's bank credit facility (due 2016), interest based on Prime and/or LIBOR plus an applicable margin, interest rate at December 31, 2013 and December 31, 2012 was 3.2% and 4.3%, respectively		$	155,000		$	71,000

	Subsidiary Borrower's credit facility (due 2016), interest based on LIBOR plus 5.0%, interest rate at December 31, 2013 was 5.3%		65,041			—

	Senior unsecured notes (due 2018), net of discount of $7.8 million and $9.7 million, respectively, which bear interest at the rate of 8.875%		717,202			715,305

	Senior unsecured notes (due 2022), which bear interest at the rate of 7.125%		250,000			250,000

	Other debt		13,229			—

	Debt classified as long-term		$	1,200,472		$	1,036,305

Schedule of Maturities of Long-term Debt [Table Text Block]	'
	Maturities for the long-term debt as of December 31, 2013 are as follows (in thousands):


	2014	$	—

	2015	—

	2016	232,734

	2017	536

	2018	725,000

	Thereafter	250,000

	Subtotal	1,208,270

	Less discount	(7,798		)
	Total outstanding debt	$	1,200,472

Schedule Of Debt Leverage	'
	The commitment fee, letter of credit fee and the applicable margins for the interest rate vary quarterly based on the Partnership's leverage ratio (as defined in the existing credit facility, being generally computed as the ratio of total funded debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges) and are as follows:


	Leverage Ratio		Base Rate		Eurodollar	Letter of
			Loans		Rate	Commitment
					Loans and	Fees
					Letter of Credit
					Fees
	Greater than or equal to 4.50 to 1.00		2.00%		3.00%	0.50%
	Greater than or equal to 4.00 to 1.00 and less than 4.50 to 1.00		1.75%		2.75%	0.50%
	Greater than or equal to 3.50 to 1.00 and less than 4.00 to 1.00		1.50%		2.50%	0.50%
	Greater than or equal to 3.00 to 1.00 and less than 3.50 to 1.00		1.25%		2.25%	0.50%
	Less than 3.00 to 1.00		1.00%		2.00%	0.38%

Income_Taxes_Table

Income Taxes (Table)	12 Months Ended
	Dec. 31, 2013
Table Text Block Supplement [Abstract]	'
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	'
	The Company provides for income taxes using the liability method. Accordingly, deferred taxes are recorded for the differences between the tax and book basis that will reverse in future periods (in thousands).


			Years Ended December 31,
			2013			2012			2011
	Current tax provision		$	7,789		$	1,742		$	1,772

	Deferred tax (benefit)		(18,003		)	(8,384		)	(4,540		)
	Tax benefit		$	(10,214	)	$	(6,642	)	$	(2,768	)
	A reconciliation of the provision for income taxes is as follows (in thousands):


			Years Ended December 31,
			2013			2012			2011
	Federal income tax on taxable corporation at statutory rate (35%)		$	(13,840	)	$	(6,692	)	$	(3,071	)
	State income tax, net		(818		)	(396		)	(182		)
	Non-deductible expenses		4,282			258			153

	Other		162			188			332

	Income tax benefit		$	(10,214	)	$	(6,642	)	$	(2,768	)
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	'
	The principal component of the Company's net deferred tax liability is as follows (in thousands):


			Years Ended
			December 31,
			2013			2012
	Deferred income tax assets:

	Accrued expenses		$	1,251		$	1,455

	Deferred transaction cost		—			863

	Net operating loss carryforward—non-current		49,499			51,488

	Investment in the Partnership		—			5,981

	Other comprehensive income		61			—

	Alternative minimum tax carry forward (AMT)		8			8

			50,819			59,795

	Less: valuation allowance		—			(5,981		)

			50,819			53,814


	Deferred income tax liabilities:
	Property, plant, equipment, and intangible assets-current		—			(7,075		)

	Property, plant, equipment, and intangible assets-long-term		(176,471		)	(184,889		)
	Other Comprehensive income		—			(56		)

	Other		(3,405		)	(2,424		)
			(179,876		)	(194,444		)
	Net deferred tax liability		$	(129,057	)	$	(140,630	)
Schedule of Unrecognized Tax Benefits Roll Forward [Table Text Block]	'
	The Company adopted the provisions of FASB ASC 740-10-25-16 on January 1, 2007. A reconciliation of the beginning and ending amount of the unrecognized tax benefits is as follows (In thousands):



	Balance as of December 31, 2011	$	2,650

	Decreases related to prior year tax positions	(383		)
	Increases related to current year tax positions	320

	Balance as of December 31, 2012	$	2,587

	Decreases related to prior year tax positions	(712		)
	Increases related to current year tax positions	519

	Balance as of December 31, 2013	$	2,394

Employee_Incentive_Plan_Tables

Employee Incentive Plan (Tables)	12 Months Ended
	Dec. 31, 2013
Crosstex Energy L.P. [Domain]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Scheduleof Share Based Compensation Restricted Stock and Restricted Stock Units Vested and Fair Value Vested Table [Text Block]	'
	A summary of the restricted incentive units' aggregate intrinsic value (market value at vesting date) and fair value of units vested (market value at date of grant) during the years ended December 31, 2013, 2012 and 2011 are provided below (in thousands):


			Years Ended December 31,
	Crosstex Energy, L.P. Restricted Incentive Units:		2013				2012			2011
	Aggregate intrinsic value of units vested		$	6,750			$	3,850		$	6,438

	Fair value of units vested		$	3,771			$	2,097		$	5,945

Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block]	'


	Crosstex Energy, L.P. Restricted Incentive Units:		Number of				Weighted
			Units				Average
							Grant-Date
							Fair Value
	Non-vested, beginning of period		1,003,159				$	13.31

	Granted		625,339				16.19

	Vested*		(396,927		)		9.5

	Forfeited		(52,648		)		13.52

	Non-vested, end of period		1,178,923				$	16.11

	Aggregate intrinsic value, end of period (in thousands)		$	32,358

	_______________________________________________________________________________

	*	Vested units include 114,831 units withheld for payroll taxes paid on behalf of employees.
Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]	'
	A summary of the unit option activity for the years ended December 31, 2013, 2012, and 2011 is provided below:


			Years Ended December 31,
			2013							2012							2011
			Number of				Weighted			Number of				Weighted			Number of			Weighted
			Units				Average			Units				Average			Units			Average
							Exercise							Exercise						Exercise
							Price							Price						Price
	Outstanding, beginning of period		349,018				$	7.25		451,574				$	6.99		611,311			$	6.77

	Exercised		(151,795		)		5.5			(87,857		)		4.96			(128,477		)	4.61

	Forfeited		(3,109		)		23.6			(14,699		)		13.39			(31,260		)	12.83

	Outstanding, end of period		194,114				$	8.36		349,018				$	7.25		451,574			$	6.99

	Options exercisable at end of period		194,114				$	8.36		286,715				$	7.52		315,742			$	7.42

	Weighted average contractual term (years) end of period:
	Options outstanding		5.2							6.1							7.2

	Options exercisable		5.2							6							6.9

	Aggregate intrinsic value end of period (in thousands):
	Options outstanding		$	3,829						$	3,016						$	4,648

	Options exercisable		$	3,829						$	2,483						$	3,260

Scheduleof Share Based Compensation Unit Options Vested and Fair Value Vested Table [Text Block]	'
	A summary of the unit options intrinsic value exercised (market value in excess of exercise price at date of exercise) and fair value of units vested (value per Black-Scholes-Merton option pricing model at date of grant) during the years ended December 31, 2013, 2012 and 2011 is provided below (in thousands):


			Years Ended December 31,
	Crosstex Energy, L.P. Unit Options:		2013				2012			2011
	Intrinsic value of units options exercised		$	2,104			$	988		$	1,527

	Fair value of unit options vested		$	254			$	277		$	563

Crosstex Energy Inc. [Domain] [Domain]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding and Exercisable [Table Text Block]	'
	CEI stock options have not been granted since 2005. A summary of the stock option activity includes officers and employees of the Partnership and directors of CEI for the years ended December 31, 2013, 2012 and 2011 is provided below:


			Years Ended December 31,
			2013						2012							2011
			Number of			Weighted			Number of			Weighted				Number of		Weighted
			Units			Average			Units			Average				Units		Average
						Exercise						Exercise						Exercise
						Price						Price						Price
	Outstanding, beginning of period		37,500			$	6.5		37,500			$	6.5			37,500		$	6.5

	Exercised		(22,500	)		6.5			—			—				—		—

	Outstanding, end of period		15,000			$	6.5		37,500			$	6.5			37,500		$	6.5

	Options exercisable at end of period		15,000			$	6.5		37,500			$	6.5			37,500		$	6.5

Scheduleof Share Based Compensation Restricted Stock and Restricted Stock Units Vested and Fair Value Vested Table [Text Block]	'
	A summary of the restricted shares' aggregate intrinsic value (market value at vesting date) and fair value of shares vested (market value at date of grant) during the years ended December 31, 2013, 2012 and 2011 is provided below (in thousands):


			Years Ended December 31,
	Crosstex Energy, Inc. Restricted Shares:		2013				2012			2011
	Aggregate intrinsic value of shares vested		$	7,593			$	4,099		$	3,915

	Fair value of shares vested		$	3,307			$	1,754		$	5,623

Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]	'
	A summary of the stock options intrinsic value exercised (market value in excess of exercise price at date of exercise) and fair value of shares vested (value per Black-Scholes-Merton option pricing model at date of grant) during the years ended December 31, 2013, 2012, and 2011 is provided below (in thousands):


			Years Ended December 31,
	Crosstex Energy, Inc. Stock Options:		2013				2012			2011
	Intrinsic value of stock options exercised		$	317			$	—		$	—

	Fair value of stock options vested		$	—			$	—		$	—

	As of December 31, 2013, all options were vested and fully expensed.
Schedule Of Shared Based Compensation Restricted Stock And Restricted Stock Units Activity Table [Text Block]	'
	A summary of the restricted stock activity which includes officers and employees of the Partnership and directors of the general partner of the Partnership for the year ended December 31, 2013, is provided below:


	Crosstex Energy, Inc. Restricted Shares:		Number of				Weighted
			Shares				Average
							Grant-Date
							Fair Value
	Non-vested, beginning of period		1,329,162				$	9.75

	Granted		632,912				15.08

	Vested*		(445,177		)		7.43

	Forfeited		(63,864		)		11.69

	Non-vested, end of period		1,453,033				$	12.69

	Aggregate intrinsic value, end of period (in thousands)		$	51,089

	_______________________________________________________________________________
	* Vested shares include 123,791 shares withheld for payroll taxes paid on behalf of employees.

Derivatives_Tables

Derivatives (Tables)	12 Months Ended
Derivatives (Tables)	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Commodity Swap	'
	The components of loss on derivatives in the consolidated statements of operations relating to commodity swaps are (in thousands):


			Years Ended December 31,
			2013				2012			2011
	Change in fair value of derivatives that are not designated for hedge accounting		$	1,674			$	(3,473	)	$	726
			$	1,674			$	(3,473	)	$	726
	Realized losses on derivatives		633				4,514			7,015
	Realized losses on derivatives		633				4,514			7,015
	Ineffective portion of derivatives designated for hedge accounting		(3		)		(35		)	(158		)
	Net losses related to commodity swaps		$	2,304			$	1,006		$	7,583
	Net losses related to commodity swaps		$	2,304			$	1,006		$	7,583
	Put option premium mark to market		—				—			193
	Put option premium mark to market		—				—			193
	Losses on derivatives		$	2,304			$	1,006		$	7,776
	Losses on derivatives		$	2,304			$	1,006		$	7,776
Fair Value of Derivative Assets and Liabilities relating to commodity swaps	'
	The fair value of derivative assets and liabilities relating to commodity swaps are as follows (in thousands):


			December 31,
			2013				2012
	Fair value of derivative assets—current, designated		$	9			$	724
	Fair value of derivative assets—current, designated		$	9			$	724
	Fair value of derivative assets—current, non-designated		293				2,510
	Fair value of derivative assets—current, non-designated		293				2,510
	Fair value of derivative assets-long term, non-designated		556				—
	Fair value of derivative assets-long term, non-designated		556				—
	Fair value of derivative liabilities—current, designated		(705		)		(105		)
	Fair value of derivative liabilities—current, non-designated		(463		)		(1,205		)
	Fair value of derivative liabilities—long term, non-designated		(755		)		—
			(755		)		—
	Net fair value of derivatives		$	(1,065	)		$	1,924
	Net fair value of derivatives		$	(1,065	)		$	1,924
Impact of Cash Flow Hedges	'
	The impact of realized gains or losses from derivatives designated as cash flow hedge contracts in the consolidated statements of operations is summarized below (in thousands):


			Years Ended December 31,
	Increase (decrease) in Midstream revenue		2013				2012			2011
	Liquids		$	768			$	1,381		$	(2,772	)
	Liquids		$	768			$	1,381		$	(2,772	)
Derivatives Other than Cash Flow Hedges	'
	The estimated fair value of derivative contracts by maturity date was as follows (in thousands):


			Maturity Periods
			Less than				One to			More than			Total
			one year				two years			two years			fair value
	December 31, 2013		$	(170	)		$	61		$	(260	)	$	(369	)
	December 31, 2013		$	(170	)		$	61		$	(260	)	$	(369	)
Schedule Of Notional Amount And Fair Value Of Derivative Instruments [Table Text Block] [Text Block]	'


			31-Dec-13
	Transaction Type		Volume			Fair Value
			(In thousands)
	Cash Flow Hedges:*
	Liquids swaps (short contracts)		(8,567	)		$	(696	)
	Total swaps designated as cash flow hedges					$	(696	)
	Total swaps designated as cash flow hedges					$	(696	)
	Mark to Market Derivatives:*
	Swing swaps (long contracts)		1,457			$	(14	)
	Swing swaps (long contracts)		1,457			$	(14	)
	Physical offsets to swing swap transactions (short contracts)		(1,147	)		—
			(1,147	)		—
	Swing swaps (short contracts)		(78	)		2
	Swing swaps (short contracts)		(78	)		2
	Physical offsets to swing swap transactions (long contracts)		78			—
			78			—
	Processing margin hedges—liquids (short contracts)		(2,662	)		(270		)
	Processing margin hedges—gas (long contracts)		291			40
	Processing margin hedges—gas (long contracts)		291			40
	Liquids swaps—non-designated (long contracts)		50,400			(537		)
	Liquids swaps—non-designated (long contracts)		50,400			(537		)
	Liquids swaps—non-designated (short contracts)		(50,400	)		428
	Liquids swaps—non-designated (short contracts)		(50,400	)		428
	Storage swap transactions (short contracts)		(100	)		(18		)
	Total mark to market derivatives					$	(369	)
	Total mark to market derivatives					$	(369	)
	_______________________________________________________________________________

	*	All are gas contracts except for liquids swaps (designated or non-designated), processing margin hedges-liquids and storage swap transactions-condensate inventory.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Derivative Instrument	'
	Net assets (liabilities) measured at fair value on a recurring basis are summarized below (in thousands):


			December 31,
			2013			2012
			Level 2			Level 2
	Commodity Swaps*		$	(1,065	)	$	1,924

	Total		$	(1,065	)	$	1,924

	_______________________________________________________________________________

	*	Unrealized gains or losses on commodity derivatives qualifying for hedge accounting are recorded in accumulated other comprehensive income at each measurement date. The fair value of derivative contracts included in assets or liabilities for risk management activities represents the amount at which the instruments could be exchanged in a current arms-length transaction adjusted for credit risk of the Partnership and/or the counterparty as required under FASB ASC 820.
Fair Value Financial Instrument	'


			31-Dec-13					31-Dec-12
			Carrying			Fair		Carrying		Fair
			Value			Value		Value		Value
	Long-term debt		$	1,200,472		$	1,281,471	$	1,036,305	$	1,118,875

	Obligations under capital lease		22,036			23,419		25,257		27,667

Commitments_and_Contingencies_

Commitments and Contingencies (Table)	12 Months Ended
	Dec. 31, 2013
Leases, Operating [Abstract]	'
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	'
	The following table summarizes the Partnership's remaining non-cancelable future payments under operating leases with initial or remaining non-cancelable lease terms in excess of one year (in thousands):


	2014	$	10,303

	2015	10,338

	2016	8,374

	2017	5,205

	2018	5,771

	Thereafter	15,733

		$	55,724

Segment_Information_Tables

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Partnership Reportable Segement	'
	Summarized financial information concerning the Partnership's reportable segments is shown in the following table.


		LIG			NTX			PNGL			ORV			Corporate			Totals
		(In thousands)
	Year Ended December 31, 2013:
	Sales to external customers	$	491,217		$	321,025		$	850,245		$	281,825		$	—		$	1,944,312

	Sales to affiliates	89,081			72,960			22,144			—			(184,185		)	—

	Purchased gas, NGLs, condensate and crude oil	(495,807		)	(229,687		)	(777,989		)	(227,689		)	184,185			(1,546,987		)

	Operating expenses	(31,699		)	(53,772		)	(30,735		)	(34,652		)	—			(150,858		)

	Segment profit	$	52,792		$	110,526		$	63,665		$	19,484		$	—		$	246,467

	Gain (loss) on derivatives	$	92		$	(1,768	)	$	(289	)	$	(339	)	$	—		$	(2,304	)

	Depreciation, amortization and impairments	$	(12,706	)	$	(79,303	)	$	(106,412	)	$	(11,591	)	$	(2,849	)	$	(212,861	)
	Capital expenditures	$	45,569		$	23,175		$	394,514		$	99,127		$	4,465		$	566,850

	Identifiable assets	$	301,431		$	991,332		$	1,003,596		$	407,121		$	145,347		$	2,848,827

	Year Ended December 31, 2012:

	Sales to external customers	$	561,389		$	269,302		$	852,560		$	108,037		$	—		$	1,791,288

	Sales to affiliates	225,542			96,177			145,569			—			(467,288		)	$	—

	Purchased gas, NGLs, condensate and crude oil	(678,188		)	(180,116		)	(924,240		)	(82,274		)	467,288			(1,397,530		)

	Operating expenses	(33,817		)	(55,582		)	(29,601		)	(11,882		)	—			$	(130,882	)

	Segment profit	$	74,926		$	129,781		$	44,288		$	13,881		$	—		$	262,876

	Gain (loss) on derivatives	$	3,440		$	(4,405	)	$	(41	)	$	—		$	—		$	(1,006	)

	Depreciation, amortization and impairments	$	(13,936	)	$	(83,492	)	$	(57,652	)	$	(4,861	)	$	(2,359	)	$	(162,300	)
	Capital expenditures	$	4,059		$	45,235		$	182,782		$	3,893		$	8,944		$	244,913

	Identifiable assets	$	279,755		$	1,057,504		$	632,962		$	316,927		$	139,327		$	2,426,475

	Year Ended December 31, 2011:

	Sales to external customers	$	811,216		$	332,026		$	870,700		$	—		$	—		$	2,013,942

	Sales to affiliates	128,130			100,527			40,185			—			(268,842		)	—

	Purchased gas, NGLs, condensate and crude oil	(809,471		)	(262,708		)	(835,440		)	—			268,842			(1,638,777		)

	Operating expenses	(35,434		)	(48,807		)	(27,537		)	—			—			(111,778		)

	Segment profit	$	94,441		$	121,038		$	47,908		$	—		$	—		$	263,387

	Gain (loss) on derivatives	$	(6,145	)	$	(1,896	)	$	265		$	—		$	—		$	(7,776	)

	Depreciation, amortization and impairments	$	(13,676	)	$	(76,535	)	$	(31,271	)	$	—		$	(3,876	)	$	(125,358	)

	Capital expenditures	$	2,820		$	73,069		$	25,618		$	—		$	2,629		$	104,136

	Identifiable assets	$	305,359		$	1,113,431		$	460,865		$	—		$	82,961		$	1,962,616

Segment Table reconciliation to Condensed Consolidated Financial Statement	'
	The following table reconciles the segment profits reported above to the operating income as reported in the consolidated statements of operations (in thousands):


		Years Ended December 31,
		2013			2012			2011
	Segment profits	$	246,467		$	262,876		$	263,387

	General and administrative expenses	(79,993		)	(65,083		)	(55,516		)
	Loss on derivatives	(2,304		)	(1,006		)	(7,776		)
	Gain (loss) on sale of property	1,055			342			(264		)

	Depreciation, amortization and impairments	(212,861		)	(162,300		)	(125,358		)
	Operating income (loss)	$	(47,636	)	$	34,829		$	74,473

Immaterial_Correction_of_Prior1

Immaterial Correction of Prior Period Financial Statements (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Changes and Error Corrections [Abstract]	'
Schedule of Error Corrections and Prior Period Adjustments [Table Text Block]	'
	The following table reflects the revenues, purchased gas costs and total operating costs and expenses as previously reported and as adjusted for the year ended December 31, 2012 (in thousands):


	As previously reported:	Year Ended December 31, 2012
	Total revenues	$	1,655,851

	Purchased gas, NGLs, condensate and crude oil	$	1,262,093

	Total operating costs and expenses	$	1,621,022

	Operating income	$	34,829


	As adjusted:
	Total revenues	$	1,791,288

	Purchased gas, NGLs, condensate and crude oil	$	1,397,530

	Total operating costs and expenses	$	1,756,459

	Operating income	$	34,829

Quarterly_Financial_Data_Table

Quarterly Financial Data (Table)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule of Quarterly Financial Information [Table Text Block]	'
	Summarized unaudited quarterly financial data is presented below.


		First			Second			Third			Fourth			Total
		(In thousands, except per share data)
	2013:00:00
	Revenues	$	445,689		$	454,737		$	468,643		$	575,243		$	1,944,312

	Operating income (loss)	$	14,130		$	5,878		$	(62,833	)	$	(4,811	)	$	(47,636	)

	Net loss attributable to the noncontrolling interest	$	(2,168	)	$	(6,744	)	$	(61,617	)	$	(12,470	)	$	(82,999	)
	Net loss attributable to the Crosstex Energy, Inc	$	(2,936	)	$	(4,667	)	$	(11,249	)	$	(10,784	)	$	(29,636	)
	Basic earnings per common share	$	(0.06	)	$	(0.09	)	$	(0.23	)	$	(0.22	)	$	(0.60	)
	Diluted earnings per common share	$	(0.06	)	$	(0.09	)	$	(0.23	)	$	(0.22	)	$	(0.60	)
	2012:00:00
	Revenues	$	425,959		$	394,402		$	444,947		$	525,980		$	1,791,288

	Operating income (loss)	$	22,074		$	18,381		$	899		$	(6,525	)	$	34,829

	Net income (loss) attributable to the noncontrolling interest	$	3,594		$	(530	)	$	(10,240	)	$	(17,083	)	$	(24,259	)

	Net loss attributable to the Crosstex Energy, Inc.	$	(825	)	$	(1,672	)	$	(4,314	)	$	(5,670	)	$	(12,481	)
	Basic earnings per common share	$	(0.02	)	$	(0.03	)	$	(0.09	)	$	(0.12	)	$	(0.26	)
	Diluted earnings per common share	$	(0.02	)	$	(0.03	)	$	(0.09	)	$	(0.12	)	$	(0.26	)

Condensed_Financial_Informatio1

Condensed Financial Information of Parent Company (Tables)	12 Months Ended
	Dec. 31, 2013
Condensed Financial Information of Parent Company Only [Abstract]	'
Condensed Financial Statements [Table Text Block]	'
	CROSSTEX ENERGY, INC. (PARENT COMPANY)
	CONDENSED BALANCE SHEETS


			December 31,
			2013				2012
			(In thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents		$	1,764			$	2,852

	Accounts receivable		633				—

	Prepaid expenses and other		483				120

	Total current assets		2,880				2,972

	Property and equipment:
	Gathering systems		3,614				—

	Construction in process		79,241				—

	Accumulated depreciation		(160		)		—

	Total property and equipment, net		82,695				—

	Intangibles		4,246				—

	Investment in the Partnership		199,885				217,425

	Other assets, net		1,112				—

	Total assets		$	290,818			$	220,397

	LIABILITIES AND STOCKHOLDERS' EQUITY
	Current liabilities:
	Accounts payable		$	6,168			$	—

	Related party payable		2,569				—

	Other current liabilities		1,153				580

	Total current liabilities		9,890				580

	Long term debt		78,270				—

	Deferred tax liability		56,733				62,151

	Other long term liabilities		47				—

	Stockholders' equity:
	Common stock		476				473

	Additional paid-in capital		307,835				274,635

	Accumulated deficit		(171,263		)		(117,583		)
	Accumulated other comprehensive loss		(58		)		141

	Stockholders' equity		136,990				157,666

	Non-controlling interest		8,888				—

	Total stockholders' equity		145,878				157,666

Total liabilities and stockholders' equity		$	290,818			$	220,397

CROSSTEX ENERGY, INC. (PARENT COMPANY)
CONDENSED STATEMENTS OF OPERATIONS




		Years ended December 31,
		2013				2012				2011
		(In thousands, except per share data)
Revenues:
Midstream		$	1,073			$	—			$	—

Total revenues		1,073				—				—

Operating costs and expenses:
Loss from investment in the Partnership		30,400				16,080				7,192

Operating expenses		513				—				—

General and administrative expenses		11,932				3,775				2,715

Depreciation and amortization		185				—				—

Total operating costs and expenses		43,030				19,855				9,907

Operating loss		(41,957		)		(19,855		)		(9,907		)
Other income (expense):
Interest and other income		(407		)		7				6

Loss before income taxes		(42,364		)		(19,848		)		(9,901		)
Income tax benefit		12,551				7,367				3,894

Net loss		(29,813		)		(12,481		)		(6,007		)
Less: Net loss attributable to the noncontrolling interest		(177		)		—				—

Net loss attributable to Crosstex Energy, Inc.		$	(29,636	)		$	(12,481	)		$	(6,007	)
Net loss per common share:
Basic		$	(0.60	)		$	(0.26	)		$	(0.12	)
Diluted		$	(0.60	)		$	(0.26	)		$	(0.12	)
Weighted average common shares outstanding:
Basic		$	47,664			$	47,384			$	47,150

Diluted		$	47,664			$	47,384			$	47,150

CROSSTEX ENERGY, INC. (PARENT COMPANY)
CONDENSED STATEMENTS OF CASH FLOWS


		Years Ended December 31,
		2013				2012				2011
		(In thousands)
Cash flows from operating activities:
Net loss		$	(29,636	)		$	(12,481	)		$	(6,007	)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization		185				—				—

Loss from investment in the Partnership		30,400				16,080				7,196

Deferred tax benefit		(12,551		)		(7,367		)		(3,896		)
Stock-based compensation		212				277				249

Interest paid in kind		1,766				—				—

Amortization of debt issue cost		343				—				—

Changes in assets and liabilities:
Accounts receivable, prepaid expenses and other		(1,017		)		(27		)		(57		)
Accounts payable, and other accrued liabilities		3,222				79				238

Net cash used in operating activities		(7,076		)		(3,439		)		(2,277		)
Cash flows from investing activities:
Additions to property and equipment		(76,649		)		—				—

Investment in the Partnership		—				(3,460		)		(163		)

Distributions from the Partnership		28,936				27,270				22,497

Net cash provided by investing activities		(47,713		)		23,810				22,334

Cash flows from financing activities:
Proceeds from borrowings		77,737				—				—

Payments on borrowings		(1,233		)		—				—

Debt refinancing cost		(1,460		)		—				—

Conversion of restricted stocks, net of stocks withheld for taxes		(2,087		)		(794		)		(1,068		)
Contributions from non-controlling partners		4,642				—				—

Common dividends paid		(24,044		)		(22,925		)		(17,872		)
Proceeds from exercise of share options		146				—				—

Net cash provided by (used in) financing activities		53,701				(23,719		)		(18,940		)

Net increase (decrease) in cash and cash equivalents		(1,088		)		(3,348		)		1,117

Cash, beginning of period		2,852				6,200				5,083

Cash, end of period		$	1,764			$	2,852			$	6,200

Non-cash transactions:
Gain from issuance of Partnership units		$	35,123			$	15,890			$	—

Stock-based compensation attributed to CEI for its restricted stock granted to Partnership officers, employees and directors		$	7,000			$	4,200			$	3,100

Organization_and_Summary_of_Si1

Organization and Summary of Significant Agreements (Details Textuals) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Schedule Of Undivided Interest Investments [Line Items]	'	'
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	15.00%	'
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	1.50%	'
Limited Liability Company or Limited Partnership, Business Organization and Operations [Abstract]	'	'
Limited Liability Company or Limited Partnership, Managing Member or General Partner, Name	'Crosstex Energy, Inc	'
Limited Liability Company or Limited Partnership, Summary of Ownership Structure [Abstract]	'	'
Limited Liability Company LLC Or Limited Partnership LP Members Or Limited Partners Ownership Interest In Units	16,414,830	'
Cash paid to acquire other party's interest in CDC's interest	'	$400
Permian Gas Processing Plant [Member]	'	'
Schedule Of Undivided Interest Investments [Line Items]	'	'
Undivided Interest Investment	50.00%	'
SLP Gas Processing Plant [Member]	'	'
Schedule Of Undivided Interest Investments [Line Items]	'	'
Undivided Interest Investment	64.29%	'
Post Amendment [Member]	'	'
Schedule Of Undivided Interest Investments [Line Items]	'	'
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	1.50%	'

Significant_Accounting_Policie3

Significant Accounting Policies (Property Plant and Equipment) (Details Textuals) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Property, Plant and Equipment [Line Items]	'	'	'
Depreciation	$99.80	$98.20	$77.80
Interest Cost	$24.50	$4	$0.90
Transmission Assets [Member] \| Minimum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, Plant and Equipment, Useful Life	'20 years	'	'
Transmission Assets [Member] \| Maximum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, Plant and Equipment, Useful Life	'30 years	'	'
Gathering Assets [Member] \| Minimum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, Plant and Equipment, Useful Life	'15 years	'	'
Gathering Assets [Member] \| Maximum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, Plant and Equipment, Useful Life	'20 years	'	'
Gas Processing Plants [Member] \| Minimum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, Plant and Equipment, Useful Life	'20 years	'	'
Other Property and Equipment [Member] \| Minimum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, Plant and Equipment, Useful Life	'3 years	'	'
Other Property and Equipment [Member] \| Maximum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, Plant and Equipment, Useful Life	'15 years	'	'

Significant_Accounting_Policie4

Significant Accounting Policies (Intangible Assets Table) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Finite-Lived Intangible Assets [Line Items]	'	'
New Date of Annual Goodwill Impairment Test	'JulyB 1, 2013	'
Finite-Lived Intangible Assets, Accumulated Amortization	($227,883)	($263,305)
Finite-Lived Intangible Assets, Net	316,222	'
Goodwill	153,802	152,627
Customer Relationships [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Finite-Lived Intangible Assets, Gross	148,456	292,658
Finite-Lived Intangible Assets, Accumulated Amortization	-65,125	-130,458
Finite-Lived Intangible Assets, Net	83,331	162,200
Dedicated and Non Dedicated Acreage [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Finite-Lived Intangible Assets, Gross	395,649	395,652
Finite-Lived Intangible Assets, Accumulated Amortization	-162,758	-132,847
Finite-Lived Intangible Assets, Net	232,891	262,805
Total Intangible [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Finite-Lived Intangible Assets, Gross	544,105	688,310
Finite-Lived Intangible Assets, Accumulated Amortization	-227,883	-263,305
Finite-Lived Intangible Assets, Net	$316,222	$425,005

Significant_Accounting_Policie5

Significant Accounting Policies (Intangible Assets Amortization) (Details Textuals) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Finite-Lived Intangible Assets [Line Items]	'	'	'
Mandatory Redemption Date 2	31-Dec-13	'	'
Amortization of Intangible Assets	$40.50	$64.10	$47.50
Minimum [Member]	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'
Finite-Lived Intangible Asset, Useful Life	'3 years	'	'
Maximum [Member]	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'
Finite-Lived Intangible Asset, Useful Life	'20 years	'	'
Weighted average period [Member]	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	'19 years	'	'

Significant_Accounting_Policie6

Significant Accounting Policies (Intangible Amortization Expense Table) (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified	Dec. 31, 2013
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]	'
2014	$35,827
2015	34,430
2016	32,944
2017	32,269
2018	31,882
Thereafter	148,870
Total	$316,222

Significant_Accounting_Policie7

Significant Accounting Policies (Investment in LLC) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Schedule of Equity Method Investments [Line Items]	'	'	'
Mandatory Redemption Date 2	31-Dec-13	'	'
Limited Liability Investment Agreement Date	22-Jun-11	'	'
Payments to Acquire Equity Method Investments	$30,594,000	$52,250,000	$35,000,000
Equity Method Investment, Ownership Percentage	30.60%	'	'
Distribution from limited liability company	17,500,000	'	'
Subsidiary or Equity Method Investee, Cumulative Percentage Ownership after All Transactions	59.00%	'	'
Initial Investment [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investment, Aggregate Cost	'	'	$35,000,000

Significant_Accounting_Policie8

Significant Accounting Policies Significant Accounting Policies (Equity Method Investment and Joint Venture) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Schedule of Equity Method Investments [Line Items]	'
Investment Commitment in Joint Venture	$76
E2 [Member]	'
Schedule of Equity Method Investments [Line Items]	'
Payments to Acquire Interest in Joint Venture	$60.70
Noncontrolling Interest, Ownership Percentage by Parent	93.70%
E2 Appalachian Compression, LLC [Member] [Member]	'
Schedule of Equity Method Investments [Line Items]	'
Noncontrolling Interest, Ownership Percentage by Parent	92.50%

Significant_Accounting_Policie9

Significant Accounting Policies (Other Policies) (Details Textuals) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Asset Retirement Obligation [Abstract]	'	'	'
Asset Retirement Obligation, Current	$500,000	$500,000	'
Acquired Finite-Lived Intangible Assets [Line Items]	'	'	'
Hedging gains or losses reclassified to earnings	1,002,000	641,000	-1,769,000
Goodwill	153,802,000	152,627,000	'
Gas Balancing Payable, Current	4,800,000	2,300,000	'
Gas Balancing Asset (Liability)	4,235,000	1,533,000	'
Other Assets, Noncurrent [Abstract]	'	'	'
New Date of Annual Goodwill Impairment Test	'JulyB 1, 2013	'	'
Deferred Finance Costs, Noncurrent, Net	$22,800,000	$26,000,000	'

Recovered_Sheet1

Significant Accounting Policies (Concentraction of Credit Risk) (Details Textuals) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Concentration Risk [Line Items]	'	'	'
Mandatory Redemption Date 2	31-Dec-13	'	'
Allowance for Doubtful Accounts Receivable, Current	629	535	'
Sales Revenue [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
ConcentrationRiskPercentage1	10.00%	10.00%	'
CustomerA [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
ConcentrationRiskPercentage1	12.60%	10.50%	12.30%

Recovered_Sheet2

Significant Accounting Policies (Share-Based Compensation Expense Schedule) (Details Textuals) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Total amount charged to income	$14,383	$9,483	$7,556
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense	3,235	2,102	1,670
General and Administrative Expense [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Total amount charged to income	12,546	8,240	6,405
Operating Expense [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Total amount charged to income	1,837	1,243	1,151
Noncontrolling Interest [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Total amount charged to income	$5,656	$3,813	$3,052

Public_Offering_of_Units_and_C2

Public Offering of Units and Certain Provisions of the Partnership Agreement (Distribution) (Issuance of Preferred Units) (Details Textuals) (USD $)

3 Months Ended

12 Months Ended

1 Months Ended

3 Months Ended

12 Months Ended

In Millions, except Share data, unless otherwise specified

Mar. 31, 2014

Dec. 31, 2013

Dec. 31, 2010

Dec. 31, 2012

Dec. 31, 2011

Jan. 19, 2010

Feb. 12, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Preferred Stock [Member]

Preferred Unit [Member]

Pre Amendment [Member]

Post Amendment [Member]

Preferred Units [Line Items]

Preferred Unit Issuance Date

19-Jan-10

EDA exhaustion date

3-Jan-14

Net Proceeds From Issuance Of Preferred Limited Partners Units

$120.80

Proceeds from Issuance of Preferred Limited Partners Units

125

General Partners' Contributed Capital

2.6

Percentage Of Distribution AllocatedTo General Partner

2.00%

Partners' Capital Account, Units, Sold in Private Placement

14,705,882

Distribution per unit excess distribution level

$0.21

Preferred Units, Cumulative Cash Distributions

$14.40

$17.20

Preferred Stock, Redemption Price Per Share

$13.25

Preferred Stock Dividend Rate Per Dollar Amount Paid In Kind

$0.36

Mandatory Redemption Date 2

31-Dec-13

Preferred Stock Paid in kind

452,186

366,260

1,570,806

Preferred Conversion Trading Price

$12.75

Preferred Conversion Trading Volume

250,000

215,000

Public_Offering_of_Units_and_C3

Public Offering of Units and Certain Provisions of the Partnership Agreement (Distribution) (Details Textuals) (USD $)

12 Months Ended

3 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

General Partner [Member]

Preferred Unit [Member]

Incentive Distribution Distribution Per Unit [Member]

Incentive Distribution Percentage [Member]

Thirteen Percent [Member]

Twenty three Percent [Member]

Fortyeight Percent [Member]

Thirteen Percent [Member]

Twenty three Percent [Member]

Fortyeight Percent [Member]

Distribution Made to Member or Limited Partner [Line Items]

Distribution per unit excess distribution level

$0.21

Percentage of distribution allocated to limited partners

100.00%

Number Of Days Before Distribution

'45

Incentive Distibution Excess Per Unit Amount

$0.25

$0.31

$0.38

Incentive Distribution Percentage Levels

13.00%

23.00%

48.00%

Incentive Distribution, Distribution

$6,390

$4,489

$2,372

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$1.33

$1.31

$1.17

Distribution Made to Limited Partner, Distributions Declared, Per Unit

$0.36

Preferred Stock Dividend Rate Per Dollar Amount Paid In Kind

$0.36

Dividends Payable, Date to be Paid

14-Feb-14

Public_Offering_of_Units_and_C4

Public Offering of Units and Certain Provisions of the Partnership Agreement (Details Textuals) (USD $)

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

1 Months Ended

3 Months Ended

12 Months Ended

Mar. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 14, 2013

Jan. 14, 2013

Dec. 31, 2012

15-May-12

Jan. 14, 2013

Jun. 14, 2013

Dec. 31, 2013

Jan. 14, 2013

Jun. 14, 2013

Dec. 31, 2010

Jan. 19, 2010

Feb. 12, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Public Placement [Member]

Greenshoe Units Sold [Member]

Private Placement [Member]

June Issuance [Member]

Preferred Stock [Member]

Preferred Unit [Member]

March EDA [Member]

May EDA [Member]

May 15, 2012 [Member]

January 14, 2013 [Member]

September 14, 2012 [Member]

January 14, 2013 [Member]

Equity Distribution [Member]

Subsidiary, Sale of Stock [Line Items]

Preferred Stock Paid in kind

452,186

366,260

1,570,806

Preferred Stock Dividend Rate Per Dollar Amount Paid In Kind

$0.36

LP units issuance date

15-May-12

14-Jan-13

14-Sep-12

14-Jun-13

Partners' Capital Account, Units, Sale of Units

1,181,628

3,348,213

Limited Partners Unit Price Per Unit

$20.33

$16.28

$15.15

$13.25

$14.55

General Partners' Contributed Capital

$3,400,000

$2,600,000

EDA commencement date

1-Mar-13

Partners' Capital Account, Units, Sold in Private Placement

5,660,378

2,700,000

14,705,882

Partners' Capital Account, Units, Sold in Public Offering

8,280,000

8,625,000

10,120,000

1,080,000

Proceeds from Issuance of Common Stock

162,000,000

158,000,000

125,500,000

Aggregate Amount Of Equity Securities Allowed Under Equity Distribution Agreement

75,000,000

Replacement EDA commencement date

1-May-13

Proceeds from Issuance of Private Placement

74,800,000

39,300,000

Proceeds from Issuance of Common Limited Partners Units

419,498,000

232,791,000

20,900,000

72,300,000

Sales Agent Commissions

300,000

900,000

EDA exhaustion date

3-Jan-14

Minority Interest Decrease From Stock Issuance

35,100,000

15,900,000

Deferred Tax Liabilities Investments Decrease

$7,200,000

$11,100,000

Public_Offering_of_Units_and_C5

Public Offering of Units and Certain Provisions of the Partnership Agreement (Incentive Distributions) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Company Share of Partnership Income Loss	$27,600,000	$15,500,000	$6,400,000
Incentive Distribution, Distribution	6,390,000	4,489,000	2,372,000
Stock-based compensation attributable to CEI's restricted shares	-6,973,000	-4,205,000	-3,119,000
General partner interest in net income (loss)	-2,138,000	-818,000	15,000
General partner interest in net loss	($2,721,000)	($534,000)	($732,000)

Asset_Acquisitions_Details_Tex

Asset Acquisitions (Details Textuals) (USD $)	12 Months Ended		0 Months Ended	3 Months Ended	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Jul. 02, 2012	Mar. 31, 2012	Dec. 31, 2013
	Dec. 31, 2013	Dec. 31, 2012	Clearfield Energy	Clearfield Energy	Clearfield Energy
Business Acquisition [Line Items]	'	'	'	'	'
Business Acquisition, Date of Acquisition Agreement	'	'	'	'	2-Jul-12
Business Acquisition, Name of Acquired Entity	'	'	'	'	'Clearfield
Payments to Acquire Businesses, Gross	'	$400,000	$215,397,000	'	'
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	'	'	'	'20 years	'
Right Of Way Option Life	'	'	'	'10 years	'
Business Sale Agreement Date	'	'	'	'	15-Oct-12
Assets Held for Sale Date of Sale	'	'	'	'	18-Jan-13
Goodwill, Purchase Accounting Adjustments	$1,200,000	'	'	'	'

Asset_Acquisitions_Clearfield_

Asset Acquisitions (Clearfield PPA) (Details) (USD $)	12 Months Ended			0 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Jul. 02, 2012	Dec. 31, 2013
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Clearfield Energy	Clearfield Energy
Business Acquisition [Line Items]	'	'	'	'	'
Midstream	$1,944,312	$1,791,288	$2,013,942	'	$108,000
Payments to Acquire Businesses, Gross	'	400	'	215,397	'
Assets acquired:	'	'	'	'	'
Current assets	'	'	'	17,622	'
Assets held for sale	'	'	'	19,358	'
Property, Plant, and Equipment	'	'	'	91,422	'
Goodwill	153,802	152,627	'	153,802	'
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill	'	'	'	37,600	'
Liabilities assumed:	'	'	'	'	'
Current liabilities	'	'	'	-28,274	'
Liabilities held for disposition	'	'	'	-1,400	'
Deferred Taxes	'	'	'	-65,228	'
Long term liabilities	'	'	'	-9,505	'
Total purchase price	'	'	'	215,397	'
Cost of Purchased Oil and Gas	$1,546,987	$1,397,530	$1,638,777	'	$94,200

Asset_Acquisitions_Proforma_De

Asset Acquisitions (Proforma) (Details) (Clearfield Energy, USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Clearfield Energy	'	'
Business Acquisition [Line Items]	'	'
Pro forma total revenues	$1,897,199	$2,266,868
Pro forma net loss	-39,021	-15,476
Business Acquisitions Pro Forma Income Loss Attributable To Parent	($14,762)	($8,460)
Basic and Diluted	($0.30)	($0.18)

Asset_Disposition_Details_Text

Asset Disposition (Details Textual) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Property, Plant and Equipment [Abstract]	'	'	'
Gain (Loss) on Disposition of Property	$1,055	$342	($264)

Long_Lived_Assets_Impairment_D

Long Lived Assets Impairment (Detail Textuals) (USD $)	12 Months Ended
Long Lived Assets Impairment (Detail Textuals) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Impairment or Disposal of Tangible Assets Disclosure [Abstract]	'	'	'
Asset Impairment Charges	$72,576,000	$0	$0
Impaired Long-Lived Assets Held and Used [Line Items]	'	'	'
Depreciation, Depletion and Amortization, Nonproduction	140,285,000	162,300,000	125,358,000
Sabine Plant	'	'	'
Impaired Long-Lived Assets Held and Used [Line Items]	'	'	'
Gross Margin	'	2,000,000	2,700,000
Depreciation, Depletion and Amortization, Nonproduction	'	28,900,000	'
Property Plant And Equipment Net 1	$18,900,000	'	'

Acquisitions_Disposition_and_I2

Acquisitions, Disposition and Impairments Acquisitions, Disposition and Impairments (Intangible Asset Impairment) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Intangible Asset Impairment [Abstract]	'	'
Eunice Plant Shutdown	1-Aug-13	'
Impairment of Intangible Assets (Excluding Goodwill)	$72,600	'
Sabine Pass Plant primary contract expiration	'	31-Mar-12
Sabine Pass plant shutdown	15-Jan-13	'

LongTerm_Debt_Indebtedness_Tab

Long-Term Debt (Indebtedness Table) (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Feb. 02, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

In Thousands, unless otherwise specified

Line of Credit [Member]

CEI Credit Facility [Member]

Unsecured Debt [Member]

Other Debt Obligations [Member]

Four Point Three Percent [Member]

Eight Point Eight Seven Five Percent [Member]

Seven Point One Two Five Percent [Member]

2016

2022

2016

Line of Credit [Member]

CEI Credit Facility [Member]

Unsecured Debt [Member]

2016

2018

2022

Debt Instrument [Line Items]

Long-term Debt

$1,200,472

$1,036,305

$155,000

$71,000

$65,041

$196,500

$13,229

$717,202

$715,305

$250,000

Line of Credit Facility, Interest Rate During Period

3.16%

4.30%

5.30%

Percentage bearing fixed interest rate

8.88%

7.13%

Debt Instrument, Unamortized Discount

$7,800

$9,700

LongTerm_Debt_Long_Term_debt_M

Long-Term Debt (Long Term debt Maturities Schedule) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Maturities of Long-term Debt [Abstract]	'	'
2014	$0	'
2015	0	'
2016	232,734	'
2017	536	'
2018	725,000	'
Thereafter	250,000	'
Subtotal	1,208,270	'
Less discount	-7,798	'
Total outstanding debt	$1,200,472	$1,036,305

LongTerm_Debt_Line_of_Credit_A

Long-Term Debt (Line of Credit Amendments) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Line of Credit Facility [Line Items]	'	'
Mandatory Redemption Date 2	31-Dec-13	'
Long-term Debt	$1,200,472,000	$1,036,305,000
Line Of Credit Facility Base Interest Rate	5.00%	'
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	0.75%	'
Line of Credit Facility, Expiration Date	5-Mar-16	'
Line Of Credit Facility Collateral Units	10,700,000	'
Line Of Credit Amendment Date2	'	'
Line of Credit Facility [Line Items]	'	'
Line of credit facility, amended date	'8/28/2013	'
Line Of Credit Amendment Date1	'	'
Line of Credit Facility [Line Items]	'	'
Line of credit facility, amended date	'1/28/2013	'
Line Of Credit Amendment Date 3 [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Line of credit facility, amended date	'1/22/2014	'
Eurodollar Rate [Member]	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	1.00%	'
Eurodollar Rate [Member] \| Greater than or equal to 4.50 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	3.00%	'
Eurodollar Rate [Member] \| Greater than or equal to 4.00 to 1.00 and less than 4.50 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	2.75%	'
Eurodollar Rate [Member] \| Greater than or equal to 3.50 to 1.00 and less than 4.00 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	2.50%	'
Eurodollar Rate [Member] \| Greater than or equal to 3.00 to 1.00 and less than 3.50 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	2.25%	'
Eurodollar Rate [Member] \| Less than 3.00 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	2.00%	'
Letter of Commitment Fee [Member] \| Greater than or equal to 4.50 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	0.50%	'
Letter of Commitment Fee [Member] \| Greater than or equal to 4.00 to 1.00 and less than 4.50 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	0.50%	'
Letter of Commitment Fee [Member] \| Greater than or equal to 3.50 to 1.00 and less than 4.00 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	0.50%	'
Letter of Commitment Fee [Member] \| Greater than or equal to 3.00 to 1.00 and less than 3.50 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	0.50%	'
Letter of Commitment Fee [Member] \| Less than 3.00 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	0.38%	'
Base Rate [Member]	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	0.50%	'
Base Rate [Member] \| Greater than or equal to 4.50 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	2.00%	'
Base Rate [Member] \| Greater than or equal to 4.00 to 1.00 and less than 4.50 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	1.75%	'
Base Rate [Member] \| Greater than or equal to 3.50 to 1.00 and less than 4.00 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	1.50%	'
Base Rate [Member] \| Greater than or equal to 3.00 to 1.00 and less than 3.50 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	1.25%	'
Base Rate [Member] \| Less than 3.00 to 1.00	'	'
Leverage Ratios [Abstract]	'	'
Percentage Rate	1.00%	'
Credit Facility	'	'
Line of Credit Facility [Line Items]	'	'
Postamendment borrowing capacity	635,000,000	'
Borrowed under existing credit facility	59,700,000	'
Avaliable borrowing capacity	420,300,000	'
Leverage Ratios [Abstract]	'	'
Available Additional Borrowings	207,100,000	'
Minimum [Member] \| March 31, 2014, June 30, 2014, September 30, 2014 and December 31, 2014 [Member]	'	'
Leverage Ratios [Abstract]	'	'
Interest Coverge Ratio	'2.25 to 1.0	'
Minimum [Member] \| After December 31, 2014 [Member]	'	'
Leverage Ratios [Abstract]	'	'
Interest Coverge Ratio	'2.50 to 1.0	'
Minimum [Member] \| Credit Facility	'	'
Leverage Ratios [Abstract]	'	'
Line of Credit Facility, Commitment Fee Percentage	0.38%	'
Maximum [Member]	'	'
Leverage Ratios [Abstract]	'	'
Senior Leverage Ratio	'2.75 to 1.0	'
Maximum [Member] \| March 31, 2014, June 30, 2014 and September 30, 2014 [Member]	'	'
Leverage Ratios [Abstract]	'	'
Interest Coverage Ratio	'5.50 to 1.0	'
Maximum [Member] \| December 31, 2014 And Thereafter [Member]	'	'
Leverage Ratios [Abstract]	'	'
Interest Coverage Ratio	'5.25 to 1.0	'
Maximum [Member] \| Credit Facility	'	'
Leverage Ratios [Abstract]	'	'
Line of Credit Facility, Commitment Fee Percentage	0.50%	'
CEI Credit Facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Long-term Debt	65,041,000	'
Avaliable borrowing capacity	25,000,000	'
Pre Amendment [Member] \| CEI Credit Facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Postamendment borrowing capacity	75,000,000	'
Post Amendment [Member] \| CEI Credit Facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Postamendment borrowing capacity	90,000,000	'
2016 \| CEI Credit Facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Long-term Debt	'	$0
Subsidiary Borrower [Domain]	'	'
Leverage Ratios [Abstract]	'	'
Line of Credit Facility, Initiation Date	5-Mar-13	'

LongTerm_Debt_Narrative_Detail

Long-Term Debt (Narrative) (Details) (USD $)	12 Months Ended
Long-Term Debt (Narrative) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Line of Credit Facility [Line Items]	'	'
Line of Credit Facility, Expiration Date	5-Mar-16	'
Long-term Debt	$1,200,472,000	$1,036,305,000
Line Of Credit Facility Collateral Units	10,700,000	'
Line Of Credit Facility Base Interest Rate	5.00%	'
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	0.75%	'
Line Of Credit Facility Loan To Equity Value Percentage	47.00%	'
CEI Credit Facility [Member] \| Post Amendment [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Line of Credit Facility, Maximum Borrowing Capacity	90,000,000	'
CEI Credit Facility [Member] \| Pre Amendment [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Line of Credit Facility, Maximum Borrowing Capacity	75,000,000	'
CEI Credit Facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Long-term Debt	65,041,000	'
Line of Credit Facility, Remaining Borrowing Capacity	25,000,000	'
Other Debt Obligations [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Line of Credit Facility, Initiation Date	4-Sep-13	'
Line of Credit Facility, Maximum Borrowing Capacity	20,000,000	'
Line of Credit Facility, Interest Rate at Period End	4.16%	'
Line of Credit Facility, Expiration Date	4-Sep-16	'
Line of Credit Facility, Amount Outstanding	12,700,000	'
Notes Payable, Noncurrent	500,000	'
Notes Payable, Maturity Date	1-Jul-17	'
Notes Payable, Interest Rate, Stated Percentage Rate Range, Minimum	3.90%	'
Notes Payable, Interest Rate, Stated Percentage Rate Range, Maximum	7.00%	'
Long-term Debt	13,229,000	'
Line of Credit Facility, Remaining Borrowing Capacity	7,300,000	'
Revolving Credit Facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Available Additional Borrowings	207,100,000	'
Line of Credit Facility, Maximum Borrowing Capacity	635,000,000	'
Line of Credit Facility, Amount Outstanding	59,700,000	'
Line of Credit Facility, Remaining Borrowing Capacity	420,300,000	'
Minimum [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Line Of Credit Facility Loan To Equity Value Percentage	42.50%	'
2016 \| CEI Credit Facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Long-term Debt	'	0
2016 \| Other Debt Obligations [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Long-term Debt	'	$0

LongTerm_Debt_Issuance_of_Debt

Long-Term Debt (Issuance of Debt Instrument) (Details) (USD $)	12 Months Ended			3 Months Ended	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2013	Dec. 31, 2013
	Dec. 31, 2013	2018 Notes	2022 Notes	2018 Notes [Member]	Moody's, B1 Rating [Member]	Standard & Poor's, B+ Rating [Member]
Debt Instrument [Line Items]	'	'	'	'	'	'
Debt Instrument, Credit Rating	'	'	'	'	'B1	'B+
Debt Instrument, Issuance Date	'	10-Feb-10	24-May-12	'	'	'
Debt Instrument, Face Amount	'	$725,000,000	$250,000,000	'	'	'
Debt Instrument, Interest Rate, Stated Percentage	'	8.88%	7.13%	'	'	'
Debt Instrument, Call Date, Earliest	'	15-Feb-14	1-Jun-17	'	'	'
Debt Instrument Call Date Mid	'	15-Feb-15	1-Jun-18	'	'	'
Debt Instrument Call Date 1 Mid	'	'	1-Jun-19	'	'	'
Debt Instrument, Call Date, Latest	'	15-Feb-16	1-Jun-20	'	'	'
Debt Instrument, Maturity Date	'	15-Feb-18	1-Jun-22	'	'	'
Selling Priceof Debt Instrument	'	97.91%	100.00%	'	'	'
Debt Instrument, Interest Rate, Effective Percentage	'	9.25%	7.13%	'	'	'
Redemption Price For Early Redepemption	'	'	107.13%	'	'	'
Redemption Amount	'	'	35.00%	'	'	'
Redemption Price 1	'	'	103.56%	'	'	'
Redemption Price 2	'	'	102.38%	'	'	'
Redemption Price 3	'	'	101.19%	'	'	'
Redemption Price 4	'	'	100.00%	'	'	'
Redemption Price 2018 Note 1	'	104.44%	'	'	'	'
Principal Outstanding After Early Redemption	'	'	65.00%	'	'	'
Redemption Days	'	'	'180	'	'	'
Fixed Charge Coverage ratio	'2.0 to 1.0	'	'	'	'	'
Redemption Price 2018 Note 2	'	102.22%	'	'	'	'
Redemption Price 2018 Note 3	'	100.00%	'	'	'	'
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed	'	'	'	101.00%	'	'

Income_Taxes_Details_Textuals

Income Taxes (Details Textuals) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified	Dec. 31, 2013
Total Operating Loss Carryforward [Member]	'
Operating Loss Carryforwards [Line Items]	'
Operating Loss Carryforwards	$130.20
State and Local Jurisdiction [Member]	'
Operating Loss Carryforwards [Line Items]	'
Operating Loss Carryforwards	$76.50

Income_Taxes_Deferred_Tax_Tabl

Income Taxes (Deferred Tax Tables) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]	'	'	'
Deferred Tax Assets, Equity Method Investments	$0	$5,981	'
Current tax provision	-7,789	-1,742	-1,772
Deferred tax benefit	-18,003	-8,384	-4,540
Income Tax Provision (Benefit)	($10,214)	($6,642)	($2,768)

Income_Taxes_Tax_Provision_Tab

Income Taxes (Tax Provision Tables) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Tax Expense (Benefit), Continuing Operations [Abstract]	'	'	'
Statutory Tax Rate	35.00%	'	'
Federal income tax on taxable corporation at statutory rate	$13,840	$6,692	$3,071
State income taxes, net	-818	-396	-182
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Amount	4,282	258	153
Other Tax Expense (Benefit)	162	188	332
Income Tax Provision (Benefit)	($10,214)	($6,642)	($2,768)

Income_Taxes_Deferred_Tax_Liab

Income Taxes (Deferred Tax Liabilities) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Deferred Tax Liabilities, Net, Classification [Abstract]	'	'
Accrued expenses	$1,251	$1,455
Deferred Finance Costs, Net	0	863
Deferred transaction cost	0	-5,981
Deferred Tax Assets, Net of Valuation Allowance	50,819	53,814
Deferred Tax Liabilities, Net, Current	0	-7,075
Deferred Tax Assets, Operating Loss Carryforwards	49,499	51,488
Deferred Tax Assets, Equity Method Investments	0	5,981
Deferred Tax Assets, Other Comprehensive Loss	61	0
Deferred Tax Assets, Tax Credit Carryforwards, Alternative Minimum Tax	8	8
Deferred Tax Assets, Gross	50,819	59,795
Deferred Tax Liabilities Long Term	-176,471	-184,889
Deferred Tax Liabilities, Other Comprehensive Income	0	-56
Deferred Tax Liabilities, Other	-3,405	-2,424
Deferred Tax Liabilities, Gross	179,876	194,444
Deferred Tax Liabilities, Net, Noncurrent	($129,057)	($140,630)

Income_Taxes_Unrecognized_Tax_

Income Taxes (Unrecognized Tax Benefit) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2010
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense [Abstract]	'	'	'
Unrecognized Tax Benefits	$2,394	$2,587	$2,650
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions	-712	-383	'
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions	$519	$320	'

Income_Taxes_Valuation_Allowan

Income Taxes Valuation Allowance (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]	'	'
Deferred Tax Assets, Gross	$50,819	$59,795
Deferred Tax Assets, Valuation Allowance	$0	$5,981

Employee_Incentive_Plans_Detai

Employee Incentive Plans (Details) (USD $)

12 Months Ended

0 Months Ended

In Thousands, except Share data, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

9-May-13

Dec. 31, 2013

Mar. 04, 2013

9-May-13

Dec. 31, 2013

Restricted Stock Units (RSUs) [Member]

Restricted Stock [Member]

Share [Member]

CELP Restricted Units [Member]

CEI Restricted Shares [Member]

Common Units [Member]

Restricted Stock Units (RSUs) [Member]

Restricted Stock [Member]

Common Stock [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Share-based Compensation Arrangement by Share-based Payment Award, Number of Additional Shares Authorized

3,470,000

1,785,000

Mandatory Redemption Date 2

31-Dec-13

Non-vested beginning of period

$13.31

$9.75

Granted

$16.19

$15.08

Vested*

$9.50

$7.43

Forfeited

$13.52

$11.69

Non-vested, end of period

$16.11

$13.31

$12.69

$9.75

Non-vested beginning of period

1,003,159

1,329,162

Granted (Units)

625,339

632,912

Vested* (Units)

-396,927

-445,177

-57,897

-60,018

Forfeited (Units)

-52,648

-63,864

Non-vested, end of period

1,178,923

1,003,159

1,453,033

1,329,162

Aggregate intrinsic value, end of period (in thousands)

$32,358

$51,089

Share based compensation arrangement by share based payment award equity instruments other than options vested in period withheld for payroll taxes

114,831

123,791

Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized

8,975,000

9,070,000

4,385,000

Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant

2,464,665

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value

$3,771

$2,097

$5,945

$3,307

$1,754

$5,623

$1,000

Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition

'1 year 2 months

'1 year 1 month

Employee_Incentive_Plans_Value

Employee Incentive Plans (Value Tables) (Details) (USD $)	12 Months Ended
Employee Incentive Plans (Value Tables) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Stock Options [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Intrinsic value of unit options exercised	$317,000	$0	$0
Fair value of units option vested	0	0	0
Restricted Stock Units (RSUs) [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Aggregate intrinsic value of units vested	6,750,000	3,850,000	6,438,000
Fair value of units vested	3,771,000	2,097,000	5,945,000
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	7,400,000	'	'
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition	'1 year 2 months	'	'
Unit Option [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Intrinsic value of unit options exercised	2,104,000	988,000	1,527,000
Fair value of units option vested	254,000	277,000	563,000
Restricted Stock [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Aggregate intrinsic value of units vested	7,593,000	4,099,000	3,915,000
Fair value of units vested	3,307,000	1,754,000	5,623,000
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$7,400,000	'	'
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition	'1 year 1 month	'	'

Employee_Incentive_Plan_Summar

Employee Incentive Plan (Summary of Partnership Unit Option) (Details) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Stock Options [Member]	'	'	'
Share Based Compenstation Arrangement By Share Based Payment Award Unit Option [Abstract]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number, Beginning Balance	37,500	37,500	37,500
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period	-22,500	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures in Period	'	0	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number, Ending Balance	15,000	37,500	37,500
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number	15,000	37,500	37,500
Options exercisable at end of period	$6.50	$6.50	$6.50
Unit Options Weighted Average Share Price [Abstract]	'	'	'
Outstanding, beginning of period	$6.50	$6.50	$6.50
Forfeited	$6.50	$0	$0
Outstanding, End of period	$6.50	$6.50	$6.50
Unit Option [Member]	'	'	'
Share Based Compenstation Arrangement By Share Based Payment Award Unit Option [Abstract]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number, Beginning Balance	349,018	451,574	611,311
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period	-151,795	-87,857	-128,477
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures in Period	-3,109	-14,699	-31,260
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number, Ending Balance	194,114	349,018	451,574
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number	194,114	286,715	315,742
Options exercisable at end of period	$8.36	$7.52	$7.42
Unit Options Weighted Average Share Price [Abstract]	'	'	'
Outstanding, beginning of period	$7.25	$6.99	$6.77
Exercised	$5.50	$4.96	$4.61
Forfeited	$23.60	$13.39	$12.83
Outstanding, End of period	$8.36	$7.25	$6.99
Weighted Average Contractual Term End Of Period [Abstract]	'	'	'
Options outstanding	'5 years 2 months	'6 years 1 month	'7 years 2 months
Options excercisable	'5 years 2 months	'6 years 0 months	'6 years 11 months
Aggregate Instrinsic Value End Of Period [Abstract]	'	'	'
Options outstanding	$3,829	$3,016	$4,648
Instrinsic value of unit options excerised	$3,829	$2,483	$3,260

Derivatives_Summary_of_Derivat

Derivatives (Summary of Derivative Income Expense) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Derivative, Gain (Loss) on Derivative, Net	$2,304	$1,006	$7,776
Loss on derivatives	2,304	1,006	7,776
Commodity Swap [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Changes in fair value of derivatives that do not qualify for hedge accounting	1,674	-3,473	726
Derivative, Gain (Loss) on Derivative, Net	633	4,514	7,015
Ineffective portion of derivatives qualifying for hedge accounting	-3	-35	-158
Put Option [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Put option premium mark to market	0	0	193
Total Gain Loss on Derivative [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Loss on derivatives	$2,304	$1,006	$7,583

Derivatives_Schedule_of_Deriva

Derivatives (Schedule of Derivative Assets Liabilities) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Designated as Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Assets, Current	$9	$724
Derivative Liabilities, Current	-705	-105
Not Designated as Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Assets, Current	293	2,510
Derivative Asset, Noncurrent	556	0
Derivative Liabilities, Current	-463	-1,205
Derivative Liability, Noncurrent	-755	0
Total [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative, Fair Value, Net	($1,065)	$1,924

Derivatives_Derivatives_Outsta

Derivatives (Derivatives Outstanding) (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified	gal
Short Contracts [Member] \| Liquids [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-50,400,000
Derivative Non Designated Assets (Liabilities), at Fair Value, Net	$428
Long Contracts [Member] \| Liquids [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-50,400,000
Derivative Non Designated Assets (Liabilities), at Fair Value, Net	-537
Cash Flow Liquid Swap [Member] \| Short Contracts [Member] \| Liquids [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-8,567,000
Cash Flow Hedges Derivative Instruments at Fair Value, Net, Total	-696
Swing Swap [Member] \| Short Contracts [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-78,000
Derivative Non Designated Assets (Liabilities), at Fair Value, Net	2
Swing Swap [Member] \| Long Contracts [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-1,457,000
Derivative Non Designated Assets (Liabilities), at Fair Value, Net	-14
Physical Offset To Swing Swap [Member] \| Short Contracts [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-1,147,000
Derivative Non Designated Assets (Liabilities), at Fair Value, Net	0
Physical Offset To Swing Swap [Member] \| Long Contracts [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-78,000
Derivative Non Designated Assets (Liabilities), at Fair Value, Net	0
Processing Margin Hedges [Member] \| Short Contracts [Member] \| Liquids [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-2,662,000
Derivative Non Designated Assets (Liabilities), at Fair Value, Net	-270
Processing Margin Hedges [Member] \| Long Contracts [Member] \| Gas [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-291,000
Derivative Non Designated Assets (Liabilities), at Fair Value, Net	40
Storage Swap [Member] \| Short Contracts [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-100,000
Derivative Non Designated Assets (Liabilities), at Fair Value, Net	($18)

Derivatives_Details_Textuals

Derivatives (Details Textuals) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Derivative [Line Items]	'
Mandatory Redemption Date 2	31-Dec-13
Maximum counterparty loss	$0.70
Maximum counterparty loss with netting feature	0.2
Cash Flow Liquid Swap [Member]	'
Derivative [Line Items]	'
Price Risk Cash Flow Hedge Unrealized Gain (Loss) to be Reclassified During Next 12 Months	$0.70

Derivatives_Impact_of_Cash_Flo

Derivatives (Impact of Cash Flow Hedges Table) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'	'
Liquids realized loss included in Midstream revenue	$768	$1,381	($2,772)

Derivatives_Derivatives_Other_

Derivatives (Derivatives Other Than Cash Flow Hedges Table) (Details) (Not Designated as Hedging Instrument [Member], USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified	Dec. 31, 2013
Not Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Less than one year	$170
One to two years	61
More than two years	260
Total Fair Value	($369)

Fair_Value_Measurement_Fair_Me

Fair Value Measurement (Fair Measurement on a Recurring Nonrecurring Basis) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'
Derivative, Gain (Loss) on Derivative, Net	($2,304)	($1,006)	($7,776)
Commodity Swap [Member]	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'
Derivative, Gain (Loss) on Derivative, Net	-633	-4,514	-7,015
Fair Value, Inputs, Level 2 [Member] \| Commodity Swap [Member] \| Fair Value, Measurements, Recurring [Member]	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'
Derivative, Gain (Loss) on Derivative, Net	($1,065)	$1,924	'

Fair_Value_Measurement_Fair_Va

Fair Value Measurement (Fair Value of Financial Instrument) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Long-term Debt	$1,200,472	$1,036,305
Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Long-term Debt	1,200,472	1,036,305
Obligations under capital lease	22,036	25,257
Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Obligations under capital lease	23,419	27,667
Long-term Debt, Fair Value	$1,281,471	$1,118,875

Fair_Value_Measurement_Details

Fair Value Measurement (Details Textuals) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Feb. 02, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2013

Other Debt Obligations [Member]

Line of Credit [Member]

Unsecured Debt [Member]

CEI Credit Facility [Member]

2016

2022

2016

Four Point Three Percent [Member]

Seven Point One Two Five Percent [Member]

Four Point Three Percent [Member]

Debt Instrument [Line Items]

Borrowed under existing credit facility

$12,700,000

Long-term Debt

$1,200,472,000

$1,036,305,000

$13,229,000

$155,000,000

$71,000,000

$196,500,000

$250,000,000

$65,041,000

Variable Interest Rate

3.16%

4.30%

5.30%

Fixed Interest Rate

7.13%

Commitments_and_Contingencies_1

Commitments and Contingencies (Leases) (Details) (USD $)	12 Months Ended
Commitments and Contingencies (Leases) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]	'	'	'
2014	$10,303,000	'	'
2015	10,338,000	'	'
2016	8,374,000	'	'
2017	5,205,000	'	'
2018	5,771,000	'	'
Thereafter	15,733,000	'	'
Operating Leases, Future Minimum Payments Due	55,724,000	'	'
Operating Leases, Rent Expense, Net [Abstract]	'	'	'
Operating Leases, Rent Expense, Net	$28,100,000	$23,200,000	$21,900,000

Commitments_and_Contingencies_2

Commitments and Contingencies (Contingencies Related to Acquisition) (Details)	12 Months Ended
	Dec. 31, 2013
Business Acquisition [Line Items]	'
Mandatory Redemption Date 2	31-Dec-13
Lig Pipeline [Member]	'
Business Acquisition [Line Items]	'
Business Acquisition, Date of Acquisition Agreement	1-Apr-04
Business Acquisition, Name of Acquired Entity	'LIG Pipeline Company
Environmental Remediation Sites, No Further Remediation Required [Member]	'
Business Acquisition [Line Items]	'
Site Contingency, Number of Sites	23
Total [Member]	'
Business Acquisition [Line Items]	'
Site Contingency, Number of Sites	25
Environmental Remediation Sites, Continuing Remediation Required [Member]	'
Business Acquisition [Line Items]	'
Site Contingency, Number of Sites	2

Commitments_and_Contingencies_3

Commitments and Contingencies (Details Textuals) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Nuisance Lawsuit [Member]	'
Loss Contingencies [Line Items]	'
Loss Contingency, Lawsuit Filing Date	'January 2012
Loss Contingency, Damages Sought, Value	$2
SLFPA for NO lawsuit [Member]	'
Loss Contingencies [Line Items]	'
Loss Contingency, Lawsuit Filing Date	'July 1, 2013

Common_Stock_Details

Common Stock (Details) (USD $)	12 Months Ended
Common Stock (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Class of Stock [Line Items]	'	'	'
Common Stock, Shares Authorized	150,000,000	150,000,000	'
Mandatory Redemption Date 2	31-Dec-13	'	'
Net Income Loss Allocated To Restricted Shares	$961,000	$307,000	$125,000
Pre October 2006 [Member]	'	'	'
Class of Stock [Line Items]	'	'	'
Total Shares Authorized	20,000,000	'	'
Common Stock, Shares Authorized	19,000,000	'	'
Preferred Stock, Shares Authorized	1,000,000	'	'
Post October 2006 [Member]	'	'	'
Class of Stock [Line Items]	'	'	'
Total Shares Authorized	150,000,000	'	'
Common Stock, Shares Authorized	140,000,000	'	'
Preferred Stock, Shares Authorized	10,000,000	'	'

Segment_Information_Details_Te

Segment Information (Details Textuals) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Sales to external customers	$1,944,312	$1,791,288	$2,013,942
Purchased gas, NGLs and crude oil	-1,546,987	-1,397,530	-1,638,777
Operating expenses	-150,858	-130,882	-111,778
Loss on derivatives	2,304	1,006	7,776
Depreciation, amortization and impairments	-212,861	-162,300	-125,358
Identifiable assets	2,848,827	2,426,475	'
LIG Operating Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales to external customers	491,217	561,389	811,216
RevenuesFromTransactionswithOtherSegmentsofSameEntity	89,081	225,542	128,130
Purchased gas, NGLs and crude oil	-495,807	-678,188	-809,471
Operating expenses	-31,699	-33,817	-35,434
Segment Profit Loss	52,792	74,926	94,441
Loss on derivatives	-92	-3,440	6,145
Depreciation, amortization and impairments	-12,706	-13,936	-13,676
Property, Plant and Equipment, Additions	45,569	4,059	2,820
Identifiable assets	301,431	279,755	305,359
NTX Operating Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales to external customers	321,025	269,302	332,026
RevenuesFromTransactionswithOtherSegmentsofSameEntity	72,960	96,177	100,527
Purchased gas, NGLs and crude oil	-229,687	-180,116	-262,708
Operating expenses	-53,772	-55,582	-48,807
Segment Profit Loss	110,526	129,781	121,038
Loss on derivatives	1,768	4,405	1,896
Depreciation, amortization and impairments	-79,303	-83,492	-76,535
Property, Plant and Equipment, Additions	23,175	45,235	73,069
Identifiable assets	991,332	1,057,504	1,113,431
PNGL Operating Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales to external customers	850,245	852,560	870,700
RevenuesFromTransactionswithOtherSegmentsofSameEntity	22,144	145,569	40,185
Purchased gas, NGLs and crude oil	-777,989	-924,240	-835,440
Operating expenses	-30,735	-29,601	-27,537
Segment Profit Loss	63,665	44,288	47,908
Loss on derivatives	289	41	-265
Depreciation, amortization and impairments	-106,412	-57,652	-31,271
Property, Plant and Equipment, Additions	394,514	182,782	25,618
Identifiable assets	1,003,596	632,962	460,865
ORV Operating Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales to external customers	281,825	108,037	0
RevenuesFromTransactionswithOtherSegmentsofSameEntity	0	0	0
Purchased gas, NGLs and crude oil	-227,689	-82,274	0
Operating expenses	-34,652	-11,882	0
Segment Profit Loss	19,484	13,881	0
Loss on derivatives	339	0	0
Depreciation, amortization and impairments	-11,591	-4,861	0
Property, Plant and Equipment, Additions	99,127	3,893	0
Identifiable assets	407,121	316,927	0
Corporate Elimination [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales to external customers	0	0	0
RevenuesFromTransactionswithOtherSegmentsofSameEntity	-184,185	-467,288	-268,842
Purchased gas, NGLs and crude oil	184,185	467,288	268,842
Operating expenses	0	0	0
Segment Profit Loss	0	0	0
Loss on derivatives	0	0	0
Depreciation, amortization and impairments	-2,849	-2,359	-3,876
Property, Plant and Equipment, Additions	4,465	8,944	2,629
Identifiable assets	145,347	139,327	82,961
Total [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales to external customers	1,944,312	1,791,288	2,013,942
RevenuesFromTransactionswithOtherSegmentsofSameEntity	0	0	0
Purchased gas, NGLs and crude oil	-1,546,987	-1,397,530	-1,638,777
Operating expenses	-150,858	-130,882	-111,778
Segment Profit Loss Total	246,467	262,876	263,387
Property, Plant and Equipment, Additions	566,850	244,913	104,136
Identifiable assets	$2,848,827	$2,426,475	$1,962,616

Segment_Information_Reconcilia

Segment Information (Reconciliation of Segment Profit to Operating Income) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting [Abstract]	'	'	'
General and administrative	($79,993)	($65,083)	($55,516)
(Gain) loss on derivatives	-2,304	-1,006	-7,776
(Gain) loss on sale of property	1,055	342	-264
Depreciation, amortization and impairments	-212,861	-162,300	-125,358
Operating income	($47,636)	$34,829	$74,473

Immaterial_Correction_of_Prior2

Immaterial Correction of Prior Period Financial Statements (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Total revenues	$1,944,312	$1,791,288	$2,013,942
Cost of Purchased Oil and Gas	1,546,987	1,397,530	1,638,777
Total operating costs and expenses	1,991,948	1,756,459	1,939,469
Operating income	-47,636	34,829	74,473
Scenario, Actual [Member]	'	'	'
Total revenues	'	1,791,288	'
Cost of Purchased Oil and Gas	'	1,397,530	'
Total operating costs and expenses	'	1,756,459	'
Operating income	'	34,829	'
Classification of New Opportunity Processing [Member] \| Scenario, Adjustment [Member]	'	'	'
Cost of Purchased Oil and Gas	'	135,400	'
Classification of New Opportunity Processing [Member] \| Scenario, Previously Reported [Member]	'	'	'
Total revenues	'	1,655,851	'
Cost of Purchased Oil and Gas	'	1,262,093	'
Total operating costs and expenses	'	1,621,022	'
Operating income	'	$34,829	'

Quarterly_Financial_Data_Detai

Quarterly Financial Data (Details) (USD $)	12 Months Ended			3 Months Ended								12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Mar. 31, 2013	Mar. 31, 2012	Jun. 30, 2013	Jun. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	First Quarter [Member]	First Quarter [Member]	Second Quarter [Member]	Second Quarter [Member]	Third Quater [Member]	Third Quater [Member]	Fourth Quarter [Member]	Fourth Quarter [Member]	Total [Member]	Total [Member]
Interim Period, Costs Not Allocable [Line Items]	'	'	'	'	'	'	'	'	'	'	'	'	'
Oil and Gas Revenue	$1,944,312	$1,791,288	$2,013,942	$445,689	$425,959	$454,737	$394,402	$468,643	$444,947	$575,243	$525,980	$1,944,312	$1,791,288
Operating Income (Loss)	-47,636	34,829	74,473	14,130	22,074	5,878	18,381	-62,833	899	-4,811	-6,525	-47,636	34,829
Net Income (Loss) Attributable to Noncontrolling Interest	-82,999	-24,259	4,728	-2,168	3,594	-6,744	-530	-61,617	-10,240	-12,470	-17,083	-82,999	-24,259
Net loss attributable to Crosstex Energy, Inc.	($29,636)	($12,481)	($6,007)	($2,936)	($825)	($4,667)	($1,672)	($11,249)	($4,314)	($10,784)	($5,670)	($29,636)	($12,481)
Earnings Per Share, Diluted	($0.60)	($0.26)	($0.12)	($0.06)	($0.02)	($0.09)	($0.03)	($0.23)	($0.09)	($0.22)	($0.12)	($0.60)	($0.26)
Earnings Per Share, Basic	($0.60)	($0.26)	($0.12)	($0.06)	($0.02)	($0.09)	($0.03)	($0.23)	($0.09)	($0.22)	($0.12)	($0.60)	($0.26)

Subsequent_Events_Subsequent_E

Subsequent Events Subsequent Events (Credit Facility) (Details) (USD $)	Feb. 28, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Feb. 28, 2014
	2014 Credit Facility [Domain]	Maximum [Member]	Base Rate [Member]	Eurodollar Rate [Member]	Line of Credit, subfacility [Domain]	Line of Credit, subfacility [Member]
		2014 Credit Facility [Domain]	2014 Credit Facility [Domain]	2014 Credit Facility [Domain]	2014 Credit Facility [Domain]	2014 Credit Facility [Member]
Subsequent Event [Line Items]	'	'	'	'	'	'
Line of Credit Facility, Initiation Date	'	'	'	'	20-Feb-14	'
Line of Credit Facility, Maximum Borrowing Capacity	$1,000,000,000	'	'	'	'	$500,000,000
Interest Coverage Ratio	'	'5.0 to 1.0	'	'	'	'
Conditional acquisition purchase price	'	$50,000,000	'	'	'	'
Conditional Interest Coverge Ratio	'	'5.5 to 1.0	'	'	'	'
Percentage Rate	'	'	0.50%	1.00%	'	'

Subsequent_Events_Subsequent_E1

Subsequent Events Subsequent Events (Notes Redemption) (Details) (USD $)	3 Months Ended			3 Months Ended
	Mar. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2014	Feb. 02, 2014	Jan. 03, 2014
				2022	2022	2022
				Unsecured Debt [Member]	Unsecured Debt [Member]	Unsecured Debt [Member]
Subsequent Event [Line Items]	'	'	'	'	'	'
Debt Instrument, Maturity Date, Description	'January 3, 2014	'	'	'	'	'
Debt Instrument, Repurchase Amount	'	'	'	'	$1,083.32	$53,500,000
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed	'	'	'	21.00%	'	'
Debt Instrument, Repurchase Date	'	'	'	2-Feb-14	'	'
Debt Instrument, Face Amount	'	'	'	'	1,000	'
Long-term Debt	'	$1,200,472,000	$1,036,305,000	'	$196,500,000	'

Condensed_Financial_Informatio2

Condensed Financial Information of Parent Company Condensed Balance Sheets (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Cash and Cash Equivalents, at Carrying Value	$1,821	$2,976	$30,343	$22,780
Accounts Receivable, Net, Current	74,196	63,690	'	'
Total current assets	313,756	260,193	'	'
Gathering System Assets	729,179	723,626	'	'
Construction in Progress, Gross	297,348	180,976	'	'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	-603,936	-504,442	'	'
Total property and equipment	2,541,719	1,976,603	'	'
Intangible Assets, Net (Excluding Goodwill)	316,222	425,005	'	'
Other Assets, Noncurrent	23,035	25,989	'	'
Total assets	2,848,827	2,426,475	'	'
Accounts Payable, Current	18,140	25,839	'	'
Accounts Payable, Current	'	48,421	'	'
Total current liabilities	337,579	276,119	'	'
Long-term debt	1,200,472	1,036,305	'	'
Deferred Tax Liabilities, Net	129,057	140,630	'	'
Other Liabilities, Noncurrent	27,077	30,256	'	'
Common Stock, Value, Issued	476	473	'	'
Additional Paid in Capital	307,835	274,635	'	'
Retained Earnings (Accumulated Deficit)	-171,263	-117,583	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	-58	141	'	'
Total Crosstex Energy, Inc. stockholders' equity	136,990	157,666	'	'
Interest of non-controlling partners in the Partnership	1,016,526	792,574	'	'
Total stockholders' equity	1,153,516	950,240	829,247	901,478
Total liabilities and stockholders' equity	2,848,827	2,426,475	'	'
Parent Company [Member]	'	'	'	'
Cash and Cash Equivalents, at Carrying Value	1,764	2,852	6,200	5,083
Accounts Receivable, Net, Current	633	0	'	'
Prepaid Expense and Other Assets	483	120	'	'
Total current assets	2,880	2,972	'	'
Gathering System Assets	3,614	0	'	'
Construction in Progress, Gross	79,241	0	'	'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	-160	0	'	'
Total property and equipment	82,695	0	'	'
Intangible Assets, Net (Excluding Goodwill)	4,246	0	'	'
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	199,885	217,425	'	'
Other Assets, Noncurrent	1,112	0	'	'
Total assets	290,818	220,397	'	'
Accounts Payable, Current	6,168	0	'	'
Accounts Payable, Related Parties, Current	2,569	0	'	'
Accounts Payable, Current	1,153	580	'	'
Total current liabilities	9,890	580	'	'
Long-term debt	78,270	0	'	'
Deferred Tax Liabilities, Net	56,733	62,151	'	'
Other Liabilities, Noncurrent	47	0	'	'
Common Stock, Value, Issued	476	473	'	'
Additional Paid in Capital	307,835	274,635	'	'
Retained Earnings (Accumulated Deficit)	-171,263	-117,583	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	-58	141	'	'
Total Crosstex Energy, Inc. stockholders' equity	136,990	157,666	'	'
Interest of non-controlling partners in the Partnership	8,888	0	'	'
Total stockholders' equity	145,878	157,666	'	'
Total liabilities and stockholders' equity	$290,818	$220,397	'	'

Condensed_Financial_Informatio3

Condensed Financial Information of Parent Company Condensed Statement of Operations (Details) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Midstream	$1,944,312	$1,791,288	$2,013,942
Income (Loss) from Equity Method Investments	-46	-3,250	0
Operating Costs and Expenses	150,858	130,882	111,778
General and Administrative Expense	79,993	65,083	55,516
Depreciation, Depletion and Amortization, Nonproduction	140,285	162,300	125,358
Total operating costs and expenses	1,991,948	1,756,459	1,939,469
Operating income (loss)	-47,636	34,829	74,473
Other Nonoperating Income (Expense)	1,600	5,054	707
Loss before non-controlling interest and income taxes	-122,849	-43,382	-4,047
Income Tax Provision (Benefit)	10,214	6,642	2,768
Net loss	-112,635	-36,740	-1,279
Net Income (Loss) Attributable to Noncontrolling Interest	-82,999	-24,259	4,728
Net loss attributable to Crosstex Energy, Inc.	-29,636	-12,481	-6,007
Earnings Per Share, Basic	($0.60)	($0.26)	($0.12)
Earnings Per Share, Diluted	($0.60)	($0.26)	($0.12)
Weighted Average Number of Shares Outstanding, Basic	47,664	47,384	47,150
Weighted Average Number of Shares Outstanding, Diluted	47,664	47,384	47,150
Parent Company [Member]	'	'	'
Midstream	1,073	0	0
Income (Loss) from Equity Method Investments	30,400	16,080	7,192
Operating Costs and Expenses	513	0	0
General and Administrative Expense	11,932	3,775	2,715
Depreciation, Depletion and Amortization, Nonproduction	185	0	0
Total operating costs and expenses	43,030	19,855	9,907
Operating income (loss)	-41,957	-19,855	-9,907
Other Nonoperating Income (Expense)	-407	7	6
Loss before non-controlling interest and income taxes	-42,364	-19,848	-9,901
Income Tax Provision (Benefit)	12,551	7,367	3,894
Net loss	-29,813	-12,481	-6,007
Net Income (Loss) Attributable to Noncontrolling Interest	-177	0	0
Net loss attributable to Crosstex Energy, Inc.	($29,636)	($12,481)	($6,007)
Earnings Per Share, Basic	($0.60)	($0.26)	($0.12)
Earnings Per Share, Diluted	($0.60)	($0.26)	($0.12)
Weighted Average Number of Shares Outstanding, Basic	47,664	47,384	47,150
Weighted Average Number of Shares Outstanding, Diluted	47,664	47,384	47,150

Condensed_Financial_Informatio4

Condensed Financial Information of Parent Company Condensed Statements of Cash Flows (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net loss attributable to Crosstex Energy, Inc.	($29,636)	($12,481)	($6,007)
Depreciation, Depletion and Amortization, Nonproduction	140,285	162,300	125,358
Deferred Income Tax Expense (Benefit)	-18,003	-8,384	-4,540
Share-based Compensation	14,383	9,483	7,556
Interest paid-in-kind	1,766	0	0
Amortization of Financing Costs	6,457	5,377	6,462
Increase (Decrease) in Accounts Receivable	-75,359	-39,120	44,121
Increase (Decrease) in Accounts Payable and Accrued Liabilities	55,486	19,744	-37,800
Net cash provided by operating activities	87,839	100,456	141,293
Payments to Acquire Property, Plant, and Equipment	-560,784	-234,849	-97,572
Investment in limited liability company	-30,594	-52,250	-35,000
Distribution from limited liability company in excess of earnings	14,172	0	0
Net cash provided by (used in) investing activities	-557,786	-490,283	-132,094
Proceeds from Issuance of Long-term Debt and Capital Securities, Net	558,126	806,500	471,250
Repayments of Long-term Debt	-397,622	-570,500	-393,308
Payments of Debt Issuance Costs	-3,508	-7,155	-3,954
Conversion of restricted stock, net of shares withheld for taxes	-2,087	-794	-1,068
Contribution from Noncontrolling Interests	4,819	0	0
Proceeds from exercise of share options	146	0	0
Net cash provided by (used in) financing activities	468,792	362,460	-1,636
Net increase (decrease) in cash and cash equivalents	-1,155	-27,367	7,563
Cash and Cash Equivalents, at Carrying Value	1,821	2,976	30,343
Gain from issuance of Partnership units	7,224	-8,610	476
Parent Company [Member]	'	'	'
Net loss attributable to Crosstex Energy, Inc.	-29,636	-12,481	-6,007
Depreciation, Depletion and Amortization, Nonproduction	185	0	0
Loss (income) from investment in the partnership	30,400	16,080	7,196
Deferred Income Tax Expense (Benefit)	-12,551	-7,367	-3,896
Share-based Compensation	212	277	249
Interest paid-in-kind	1,766	0	0
Amortization of Financing Costs	343	0	0
Increase (Decrease) in Accounts Receivable	-1,017	-27	-57
Increase (Decrease) in Accounts Payable and Accrued Liabilities	3,222	79	238
Net cash provided by operating activities	-7,076	-3,439	-2,277
Payments to Acquire Property, Plant, and Equipment	-76,649	0	0
Investment in limited liability company	0	-3,460	-163
Distribution from limited liability company in excess of earnings	28,936	27,270	22,497
Net cash provided by (used in) investing activities	-47,713	23,810	22,334
Proceeds from Issuance of Long-term Debt and Capital Securities, Net	77,737	0	0
Repayments of Long-term Debt	-1,233	0	0
Payments of Debt Issuance Costs	-1,460	0	0
Conversion of restricted stock, net of shares withheld for taxes	-2,087	-794	-1,068
Contribution from Noncontrolling Interests	4,642	0	0
Payments of Dividends	-24,044	-22,925	-17,872
Proceeds from exercise of share options	146	0	0
Net cash provided by (used in) financing activities	53,701	-23,719	-18,940
Net increase (decrease) in cash and cash equivalents	-1,088	-3,348	1,117
Cash and Cash Equivalents, at Carrying Value	1,764	2,852	6,200
Gain from issuance of Partnership units	35,123	15,890	0
ShareBasedCompesationNonCash	$7,000	$4,200	$3,100