Third Coast Midstream (AMID) 10-K 11 Mar 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Jun. 28, 2013	Jun. 30, 2012	Mar. 07, 2014	Mar. 07, 2014	Mar. 07, 2014
				Limited Partner Common Units	Series A [Member]	Series B [Member]
Entity Registrant Name	'American Midstream Partners, LP	'	'	'	'	'
Entity Central Index Key	'0001513965	'	'	'	'	'
Document Type	'10-K	'	'	'	'	'
Document Period End Date	31-Dec-13	'	'	'	'	'
Amendment Flag	'false	'	'	'	'	'
Document Fiscal Year Focus	'2013	'	'	'	'	'
Document Fiscal Period Focus	'FY	'	'	'	'	'
Current Fiscal Year End Date	'--12-31	'	'	'	'	'
Entity Well-known Seasoned Issuer	'No	'	'	'	'	'
Entity Voluntary Filers	'No	'	'	'	'	'
Entity Current Reporting Status	'Yes	'	'	'	'	'
Entity Filer Category	'Non-accelerated Filer	'	'	'	'	'
Entity Public Float	'	$83,928,303	$0	'	'	'
Entity Common Stock, Shares Outstanding	7,414,077	'	'	11,097,144	5,353,970	1,168,225

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets	'	'
Cash and cash equivalents	$393	$576
Accounts receivable	6,822	1,958
Unbilled revenue	22,005	21,512
Risk management assets	473	969
Other current assets	7,497	3,226
Assets Held-for-sale, Current	1,268	0
Total current assets	38,458	28,241
Property, plant and equipment, net	312,510	223,819
Intangible Assets, Net (Excluding Goodwill)	3,682	0
Goodwill	16,447	0
Other assets, net	9,064	4,636
Assets Held-for-sale, Other, Noncurrent	1,914	0
Total assets	382,075	256,696
Current liabilities	'	'
Accounts payable	3,261	5,527
Accrued gas purchases	16,394	17,034
Accrued Liabilities and Other Liabilities	15,058	9,619
Long-term Debt, Current Maturities	2,048	0
Risk management liabilities	423	0
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	95	0
Total current liabilities	38,290	32,180
Derivative Liabilities, Noncurrent	101	0
Asset Retirement Obligation	34,636	8,319
Other liabilities	191	309
Long-term debt	130,735	128,285
Deferred Tax Liabilities, Net	4,749	0
Liabilities of Disposal Group, Including Discontinued Operation, Current	1,106	0
Total liabilities	208,797	169,093
Commitments and contingencies (see Note 18)	'	'
Temporary Equity, Carrying Amount, Including Portion Attributable to Noncontrolling Interests	94,811	0
Equity and partnersb capital	'	'
General partner interest (185 thousand units issued and outstanding as of December 31, 2013, and December 31, 2012)	2,696	548
Limited partner interest (7,414 and 9,165 thousand units issued and outstanding as of December 31, 2013, and December 31, 2012, respectively)	71,039	79,266
Accumulated other comprehensive income	104	351
Total partnersb capital	73,839	80,165
Noncontrolling interest	4,628	7,438
Total equity and partners' capital	78,467	87,603
Total liabilities, equity and partners' capital	$382,075	$256,696

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical)	Dec. 31, 2013	Dec. 31, 2012	Mar. 07, 2014
			Series A [Member]
Statement of Financial Position [Abstract]	'	'	'
General partner interest units, outstanding	185,000	185,000	'
Limited partner common units, outstanding	7,414,000	9,165,000	'
Entity Common Stock, Shares Outstanding	7,414,077	'	5,353,970
Preferred Units, Outstanding	5,279,000	'	'

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	3 Months Ended								12 Months Ended
Share data in Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Revenue	'	'	'	'	'	'	'	'	$292,626,000	$194,843,000	$233,169,000
Realized gain (loss) on early termination of commodity derivatives	'	'	'	'	'	'	'	'	0	0	-2,998,000
Unrealized gain (loss) on commodity derivatives	'	'	'	'	'	'	'	'	28,000	3,400,000	-2,452,000
Total revenue	76,108,000	79,536,000	77,608,000	59,402,000	56,663,000	53,401,000	43,322,000	44,857,000	292,654,000	198,243,000	227,719,000
Operating expenses:	'	'	'	'	'	'	'	'	'	'	'
Purchases of natural gas, NGLs and condensate	'	'	'	'	'	'	'	'	214,149,000	145,172,000	187,398,000
Direct operating expenses	'	'	'	'	'	'	'	'	29,553,000	16,798,000	11,419,000
Selling, general and administrative expenses	'	'	'	'	'	'	'	'	21,402,000	14,309,000	11,082,000
Advisory services agreement termination fee	'	'	'	'	'	'	'	'	0	0	2,500,000
Equity compensation expense	'	'	'	'	'	'	'	'	2,094,000	1,783,000	3,357,000
Depreciation and accretion expense	'	'	'	'	'	'	'	'	29,999,000	21,284,000	20,449,000
Total operating expenses	'	'	'	'	'	'	'	'	297,197,000	199,346,000	236,205,000
Gain (loss) on acquisition of assets	'	'	'	'	'	'	'	'	0	0	565,000
Gain (loss) on involuntary conversion of property, plant and equipment	'	'	'	400,000	'	'	'	'	343,000	-1,021,000	0
Gain on sale of assets, net	'	'	'	'	'	'	'	'	0	123,000	399,000
Impairment of Long-Lived Assets Held-for-use	-3,000,000	'	-15,200,000	-100,000	'	'	'	'	-18,155,000	0	0
Operating (loss) income	-2,625,000	-210,000	-17,780,000	-1,740,000	-4,982,000	-2,513,000	3,077,000	2,417,000	-22,355,000	-2,001,000	-7,522,000
Other income (expenses):	'	'	'	'	'	'	'	'	'	'	'
Interest expense	'	'	'	'	'	'	'	'	-9,291,000	-4,570,000	-4,508,000
Net loss	'	'	'	'	'	'	'	'	-33,406,000	-6,252,000	-11,698,000
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	633,000	256,000	'
Net income attributable to noncontrolling interests	100,000	190,000	188,000	155,000	7,000	249,000	0	0	'	'	'
Net loss attributable to the Partnership	-5,641,000	-2,731,000	-22,114,000	-3,553,000	-6,251,000	-4,275,000	2,327,000	1,691,000	-34,039,000	-6,508,000	-11,698,000
General partner's interest in net income (loss)	-209,000	-221,000	-905,000	-70,000	-124,000	-85,000	46,000	34,000	'	'	'
Limited partnersb interest in net income (loss)	-5,432,000	-2,510,000	-21,209,000	-3,483,000	-6,127,000	-4,190,000	2,281,000	1,657,000	-55,834,000	-6,378,000	-11,457,000
Income (Loss) from Continuing Operations, Per Basic and Diluted Share	'	'	'	'	'	'	'	'	($6.76)	($0.73)	($1.68)
Income (Loss) from Continuing Operations, Per Outstanding Limited Partnership Unit, Basic	-1.55	-0.82	-4	-0.39	-0.69	-0.46	0.24	0.18	'	'	'
Income (Loss) from Discontinued Operations, Net of Tax, Per Outstanding Limited Partnership Unit, Basic	-0.07	0.02	-0.2	0.01	0.02	0	0.01	0	'	'	'
Limited partnersb net income (loss) per unit (basic and diluted)	-1.62	-0.8	-4.2	-0.38	-0.67	-0.46	0.25	0.18	'	'	'
Basic and diluted	'	'	'	'	'	'	'	'	7,981	9,113	6,997
Earnings Per Share, Basic and Diluted	'	'	'	'	'	'	'	'	($7)	($0.70)	($1.64)
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic and Diluted Share	'	'	'	'	'	'	'	'	($0.24)	$0.03	$0.04
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Noncontrolling Interest	'	'	'	'	'	'	'	'	-31,646,000	-6,571,000	-12,030,000
Income Tax Expense (Benefit), Continuing Operations	'	'	'	'	'	'	'	'	495,000	0	0
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	-5,052,000	-2,632,000	-19,996,000	-3,471,000	-6,469,000	-4,014,000	2,252,000	1,660,000	-31,151,000	-6,571,000	-12,030,000
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	-489,000	91,000	-1,930,000	73,000	225,000	-12,000	75,000	31,000	-2,255,000	319,000	332,000
General Partner Interest	'	'	'	'	'	'	'	'	'	'	'
Other income (expenses):	'	'	'	'	'	'	'	'	'	'	'
Net loss	'	'	'	'	'	'	'	'	-1,405,000	'	'
General partner's interest in net income (loss)	'	'	'	'	'	'	'	'	'	-129,000	-233,000
Limited Partner [Member]	'	'	'	'	'	'	'	'	'	'	'
Other income (expenses):	'	'	'	'	'	'	'	'	'	'	'
Net loss	'	'	'	'	'	'	'	'	-32,634,000	'	'
Limited partnersb interest in net income (loss)	'	'	'	'	'	'	'	'	'	($6,379,000)	($11,465,000)

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 Other Comprehensive Income [Abstract]	'	'	'
Net loss	($33,406)	($6,252)	($11,698)
Unrealized (loss) gain on post retirement benefit plan assets and liabilities	'	-64	359
Comprehensive loss	-33,653	-6,316	-11,339
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	633	256	'
Comprehensive loss attributable to Partnership	($34,286)	($6,572)	($11,339)

Consolidated_Statements_of_Cha

Consolidated Statements of Changes in Partners' Capital and Noncontrolling Interest (USD $)	Total	Limited Partner Interest	General Partner Interest	Accumulated Other Comprehensive Income	Total Partners Capital	Noncontrolling Interest	Blackwater [Member]	Blackwater [Member]	Blackwater [Member]	Blackwater [Member]	Blackwater [Member]
							Limited Partner Interest	General Partner Interest	Accumulated Other Comprehensive Income	Total Partners Capital	Noncontrolling Interest
Beginning Balance at Dec. 31, 2010	'	$83,624,000	$2,124,000	$56,000	$85,804,000	$0	'	'	'	'	'
Limited partnersb interest in net income (loss)	-11,457,000	-11,465,000	'	'	'	'	'	'	'	'	'
General partner's interest in net income (loss)	'	'	-233,000	'	'	'	'	'	'	'	'
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	0	'	'	'	'	'	'	'	'	'	'
Net (loss) income	-11,698,000	'	'	0	-11,698,000	'	'	'	'	'	'
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	'	'	'	'	'	0	'	'	'	'	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	-11,698,000	'	'	'	'	'	'	'	'	'	'
Partners' Capital Account, Public Sale of Units Net of Offering Costs	-69,085,000	69,085,000	0	0	69,085,000	0	'	'	'	'	'
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	0	'	'	'	'	'	'	'	'	'	'
Unit holder distributions	-864,000	-42,682,000	-864,000	0	-43,546,000	0	'	'	'	0	'
LTIP vesting	'	-1,286,000	-1,286,000	0	0	0	'	'	'	'	'
Tax netting repurchase	'	215,000	0	0	215,000	0	'	'	'	'	'
Unit based compensation	'	257,000	1,350,000	0	1,607,000	0	'	'	'	'	'
Other comprehensive income (loss)	0	'	0	359,000	359,000	0	'	'	'	'	'
Partners' Capital Account, Distributions to Existing Interest	0	'	'	'	'	'	'	'	'	'	'
Ending Balance at Dec. 31, 2011	'	99,890,000	1,091,000	415,000	101,396,000	0	'	'	'	'	'
Noncontrolling Interest, Increase from Business Combination	'	0	0	0	0	7,407,000	'	'	'	'	'
Limited partnersb interest in net income (loss)	-6,378,000	-6,379,000	'	'	'	'	'	'	'	'	'
General partner's interest in net income (loss)	'	'	-129,000	'	'	'	'	'	'	'	'
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	0	'	'	'	'	'	'	'	'	'	'
Net (loss) income	-6,508,000	'	'	'	-6,508,000	'	'	'	'	'	'
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	256,000	'	'	'	'	'	'	'	'	'	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	-6,252,000	'	'	0	'	'	'	'	'	'	'
Partners' Capital Account, Public Sale of Units Net of Offering Costs	0	'	'	'	'	'	'	'	'	'	'
Unit holder contributions	'	0	13,000	0	'	'	'	'	'	'	'
Recapitalization	'	'	'	'	-13,000	0	'	'	'	'	'
Issuance of common units to public, net of offering costs	'	'	'	'	'	0	'	'	'	'	'
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	225,000	0	0	0	0	-225,000	'	'	'	'	'
Unit holder distributions	-322,000	-15,748,000	-322,000	0	-16,070,000	'	'	'	'	0	'
LTIP vesting	'	-1,888,000	-1,888,000	0	0	0	'	'	'	'	'
Tax netting repurchase	'	-385,000	0	0	385,000	0	'	'	'	'	'
Unit based compensation	'	0	1,783,000	0	1,783,000	0	'	'	'	'	'
Other comprehensive income (loss)	'	0	0	-64,000	-64,000	0	'	'	'	'	'
Partners' Capital Account, Distributions to Existing Interest	0	'	'	'	'	'	'	'	'	'	'
Ending Balance at Dec. 31, 2012	80,165,000	79,266,000	548,000	351,000	80,165,000	7,438,000	'	'	'	'	'
Limited partnersb interest in net income (loss)	-55,834,000	'	'	'	'	'	'	'	'	'	'
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	752,000	-1,993,000	-37,000	0	-2,030,000	-2,782,000	'	'	'	'	'
Net (loss) income	-34,039,000	'	'	'	-34,039,000	'	'	'	'	'	'
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	633,000	'	'	'	633,000	'	'	'	'	'	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	-33,406,000	-32,634,000	-1,405,000	0	'	633,000	'	'	'	'	'
Partners' Capital Account, Public Sale of Units Net of Offering Costs	-54,853,000	54,853,000	0	0	54,853,000	0	'	'	'	'	'
Unit holder contributions	'	0	12,500,000	0	12,500,000	0	0	22,696,000	0	22,696,000	0
Issuance of common units to public, net of offering costs	'	'	'	'	'	0	'	'	'	'	0
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	661,000	0	0	0	0	-661,000	'	'	'	'	'
Unit holder distributions	27,650,000	-21,628,000	-623,000	0	-22,251,000	'	-3,052,000	-30,702,000	0	-27,650,000	'
LTIP vesting	'	-2,067,000	-2,067,000	0	0	0	'	'	'	'	'
Tax netting repurchase	'	-630,000	0	0	630,000	0	'	'	'	'	'
Unit based compensation	'	0	2,024,000	0	2,024,000	0	'	'	'	'	'
Other comprehensive income (loss)	'	0	0	-247,000	'	0	'	'	'	'	'
Partners' Capital Account, Distributions to Existing Interest	-15,612,000	-15,300,000	-312,000	0	'	0	'	'	'	'	'
Ending Balance at Dec. 31, 2013	$73,839,000	$71,039,000	$2,696,000	$104,000	$73,839,000	$4,628,000	'	'	'	'	'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Statement of Cash Flows [Abstract]	'	'	'
Cash and cash equivalents, including discontinued operations	$401,000	$576,000	'
Depreciation, Depletion and Amortization	29,999,000	21,284,000	20,449,000
Depreciation and Accretion Expense, Including Discontinued Operation	'	21,414,000	20,705,000
Partners' Capital Account, Distributions to Existing Interest	15,612,000	0	0
Accrued Unitholder Distributions	4,811,000	0	0
Net loss	-33,406,000	-6,252,000	-11,698,000
Adjustments to reconcile net income (loss) to net cash provided (used) in operating activities:	'	'	'
Amortization of deferred financing costs	1,334,000	716,000	1,262,000
Amortization of Weather Derivative Premium	662,000	0	0
Amortization of weather derivative premium	1,505,000	-992,000	849,000
Unit based compensation	2,094,000	1,783,000	1,607,000
OPEB plan net periodic (benefit) cost	-73,000	-88,000	-82,000
OPEB plan net periodic cost (benefit)	0	0	-565,000
Gain on acquisition of assets	-343,000	1,021,000	0
(Gain) loss on involuntary conversion of property, plant and equipment	0	-123,000	-399,000
Gain on sale of assets, including discontinued operations	-75,000	128,000	'
Impairment of Long-Lived Assets Held-for-use	-18,155,000	0	0
Changes in operating assets and liabilities, net of effects of assets acquired and liabilities:	'	'	'
Accounts receivable	-790,000	-740,000	-562,000
Loss on impairment of noncurrent assets held for sale	2,400,000	0	0
Deferred Income Tax Expense (Benefit), including discontinued operations	-847,000	0	0
Loss on impairment of noncurrent assets held for sale	-226,000	2,768,000	2,449,000
Deferred Income Tax Expense (Benefit)	495,000	'	'
Deferred tax benefit	-1,147,000	-156,000	-670,000
Other current assets	-1,614,000	984,000	-1,800,000
Other assets, net	-823,000	-57,000	-54,000
Accounts payable	-845,000	1,197,000	-218,000
Accrued gas purchases	462,000	-1,711,000	-3,991,000
Accrued expenses and other current liabilities	769,000	-943,000	4,410,000
Other liabilities	-118,000	-468,000	-811,000
Net cash provided (used) in operating activities	17,223,000	18,348,000	10,432,000
Acquisition Costs, Period Cost	0	-51,377,000	-35,500,000
Cash flows from investing activities	'	'	'
Additions to property, plant and equipment	-27,196,000	-11,705,000	-6,369,000
Proceeds from disposals of property, plant and equipment	500,000	128,000	125,000
Cash flows from investing activities	482,000	527,000	0
Increase (Decrease) in Restricted Cash	-2,000,000	0	0
Cost of acquisitions, net of cash acquired	-28,214,000	-62,427,000	-41,744,000
Cash flows from financing activities	'	'	'
Proceeds from disposal of property, plant and equipment	13,075,000	13,000	0
Unit holder distributions	-16,120,000	-16,070,000	-43,546,000
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	-661,000	-225,000	0
Partners' Capital Account, Public Sale of Units Net of Offering Costs	54,853,000	0	69,085,000
Unit holder contributions	-630,000	-385,000	-215,000
Payment on other loan	-2,640,000	0	-615,000
Proceeds from Issuance of Convertible Preferred Units	14,393,000	0	0
Issuance of Series A Convertible Preferred Units	-2,113,000	-1,564,000	-2,489,000
Unit holder distributions	27,650,000	-322,000	-864,000
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	-752,000	0	0
Proceeds From Loans Payable	3,795,000	0	0
Payments on long-term debt	-131,571,000	-59,230,000	-120,670,000
Borrowings on long-term debt	134,021,000	121,245,000	130,570,000
Deferred debt issuance costs	10,816,000	43,784,000	32,120,000
Payments on other debt	-175,000	-295,000	808,000
Cash and cash equivalents	'	'	'
Beginning of period	576,000	871,000	63,000
End of period	393,000	576,000	871,000
Supplemental cash flow information	'	'	'
Interest payments	6,416,000	3,185,000	3,349,000
Supplemental non-cash information	'	'	'
Net increase (decrease) in cash and cash equivalents	5,181,000	6,968,000	75,000
Cash and cash equivalents	0	141,000	872,000
Repayments of Other Debt	-34,730,000	0	0
Proceeds from Other Debt	27,546,000	0	0
Repayments of Related Party Debt	($20,000,000)	$0	$0

Organization_and_Basis_of_Pres

Organization and Basis of Presentation	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization and Basis of Presentation	'
	Organization and Basis of Presentation
	Nature of business
	American Midstream Partners, LP (the “Partnership”), was formed on August 20, 2009 as a Delaware limited partnership for the purpose of operating, developing and acquiring a diversified portfolio of midstream energy assets. We provide natural gas gathering, treating, processing, fractionating, marketing and transportation services primarily in the Gulf Coast and Southeast regions of the United States through our ownership and operation of eleven gathering systems, two processing facilities, one fractionation facility, four terminal sites, three interstate pipelines and five intrastate pipelines. We also own a 50% undivided, non-operating interest in a processing plant located in southern Louisiana. Recently, we became an owner, developer and operator of petroleum, agricultural, and chemical liquid terminal storage facilities.
	We hold our assets in a series of wholly owned limited liability companies as well as a limited partnership. Our capital accounts consist of general partner interests and limited partner interests.
	Our interstate natural gas pipeline assets transport natural gas through the Federal Energy Regulatory Commission (“FERC”) regulated interstate natural gas pipelines in Louisiana, Mississippi, Alabama and Tennessee. Our interstate pipelines include:
	•	High Point Gas Transmission, LLC, which owns and operates approximately 400 miles of intrastate pipeline and is connected to 40 meters with 32 active producers and offers processing options at the Toca processing plant with delivery to Southern Natural Gas available downstream of the processing plant in Louisiana;
	•	American Midstream (Midla), LLC, which owns and operates approximately 370 miles of interstate pipeline that runs from the Monroe gas field in northern Louisiana south through Mississippi to Baton Rouge, Louisiana.
	•	American Midstream (AlaTenn), LLC, which owns and operates approximately 295 miles of interstate pipeline that runs through the Tennessee River Valley from Selmer, Tennessee, to Huntsville, Alabama and serves an eight-county area in Alabama, Mississippi and Tennessee.
	ArcLight Transactions
	On April 15, 2013, the Partnership, American Midstream GP, LLC, (our "General Partner") and AIM Midstream Holdings, LLC ("AIM Midstream Holdings"), an affiliate of American Infrastructure MLP Fund, entered into agreements (the "ArcLight Transactions") with High Point Infrastructure Partners, LLC ("HPIP"), an affiliate of ArcLight Capital Partners, LLC, pursuant to which HPIP (i) acquired 90% of our General Partner and all of our subordinated units from AIM Midstream Holdings and (ii) contributed certain midstream assets and $15.0 million in cash to us in exchange for 5,142,857 newly issued convertible preferred units (the “Series A Units”) issued by the Partnership. Of the cash consideration paid by HPIP, approximately $2.5 million was used to pay certain transaction expenses of HPIP, and the remaining approximately $12.5 million was used to repay borrowings outstanding under the Partnership's credit facility in connection with the Fourth Amendment to our credit agreement ("Fourth Amendment"). As a result of these transactions, which were also consummated on April 15, 2013, HPIP acquired both control of our General Partner and a majority of our outstanding limited partner interests. The midstream assets contributed by HPIP consist of approximately 700 miles of natural gas and liquids pipeline assets located in southeast Louisiana and the shallow water and deep shelf Gulf of Mexico (commonly referred to as the "High Point System"). The High Point System gathers natural gas from both onshore and offshore producing regions around southeast Louisiana. The onshore footprint is in Plaquemines and St. Bernard parishes, Louisiana. The offshore footprint consists of the following federal Gulf of Mexico zones: Mississippi Canyon, Viosca Knoll, West Delta, Main Pass, South Pass and Breton Sound. Natural gas is collected at more than 75 receipt points that connect to hundreds of wells targeting various geological zones in water depths up to 1,000 feet, with an emphasis on oil and liquids-rich reservoirs. The High Point System is comprised of FERC-regulated transmission assets and non-jurisdictional assets, both of which accept natural gas from well production and interconnected pipeline systems. Natural gas is delivered to the Toca Gas Processing Plant, operated by Enterprise, where the products are processed and the residue gas sent to an unaffiliated interstate system owned by Kinder Morgan. See Note 2 "Acquisitions" for further information.
	Equity Restructuring
	Effective August 9, 2013, we executed an equity restructuring agreement ("Equity Restructuring") with our General Partner and HPIP. As part of the Equity Restructuring, the Partnership's 4,526,066 subordinated units and previous incentive distribution rights (the “former IDRs,” all of which were owned by our General Partner, which is controlled by HPIP) were combined into and restructured as a new class of incentive distribution rights (the “new IDRs”). Upon the issuance of the new IDRs, the subordinated units and former IDRs were cancelled. The new IDRs were allocated 85.02% to HPIP and 14.98% to our General Partner. The new IDRs entitle the holders of our incentive distribution rights to receive 48% of any quarterly cash distributions from available cash after the Partnership's common unitholders have received the full minimum quarterly distribution (0.4125 per unit) for each quarter plus any arrearages from prior quarters (of which there are currently none).
	Following the announcement of the Equity Restructuring Agreement, AIM Midstream Holdings filed an action in Delaware Chancery Court against HPIP and our General Partner seeking either rescission of the Equity Restructuring Agreement or, in the alternative, monetary damages. As a result of the action filed by AIM Midstream Holdings, the warrants that were issued by the Partnership, in conjunction with the Equity Restructuring, to our general partner for subsequent conveyance to AIM Midstream Holdings were cancelled effective August 29, 2013. In addition to the action filed by AIM Midstream Holdings, the escrowed funds of $12.5 million were not released to us. Accordingly, HPIP contributed $12.5 million in cash to us, which was used to satisfy obligations under our credit agreement and was accounted for as a contribution from our general partner.
	On February 5, 2014, we, HPIP and our general partner entered into a settlement (the “Settlement”) with AIM Midstream Holdings regarding the action filed in Delaware Chancery Court by AIM Midstream Holdings. Under the Settlement, among other things:
	·      HPIP and AIM Midstream Holdings amended the limited liability company agreement of our General Partner ("LLC Amendment") to, among other things, amend the Sharing Percentages (as defined therein) such that HPIP’s sharing percentage thereafter is 95% and AIM Midstream Holdings’s Sharing Percentage is 5%;
	·      HPIP transferred all of the 85.02% of our outstanding new IDRs held by HPIP to our General Partner such that our General Partner owns 100% of the outstanding new IDRs; and
	·      we issued to AIM Midstream Holdings a warrant to purchase up to 300,000 common units of the Partnership at an exercise price of $0.01 per common unit (the “Warrant”), which Warrant, among other terms, (i) is exercisable at any time on or after February 8, 2014 until the tenth anniversary of February 5, 2014, (ii) contains cashless exercise provisions and (iii) contains customary anti-dilution and other protections. The Warrant was exercised on February 21, 2014.
	Blackwater Terminals
	On December 17, 2013, the Partnership completed the Blackwater Acquisition, an owner, developer and operator of petroleum, agricultural, and chemical liquid terminal storage facilities. Blackwater operates 1.3 million barrels of storage capacity across four marine terminal sites located in Westwego, Louisiana; Brunswick, Georgia; Harvey, Louisiana; and Salisbury, Maryland. See Note 2 "Acquisitions" for further information.
	Basis of presentation
	The accompanying financial statements and related notes present our consolidated financial position as of December 31, 2013 and 2012, and results of operations, comprehensive income, changes in partners' capital and noncontrolling interest, and cash flows for the years ended December 31, 2013, 2012 and 2011.
	We have prepared the consolidated financial statements in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The accompanying consolidated financial statements include accounts of American Midstream Partners, LP, and its controlled subsidiaries. All significant inter-company accounts and transactions have been eliminated in the preparation of the accompanying consolidated financial statements. We have made reclassifications to amounts reported in prior period consolidated financial statements to conform with current year presentation. These reclassifications did not have an impact on net income for the period previously reported.
	The results of operations for acquisitions accounted for as business combinations have been included in the consolidated financial statements since their respective acquisition dates. See Note 2 "Acquisitions" for further information.
	Effective December 17, 2013, Blackwater was acquired by the Partnership, in the form of the Acquisition described above, from ArcLight. However, as of April 15, 2013, an affiliate of ArcLight acquired controlling interest of the Partnership, also described above, at which time Blackwater was also an affiliate of ArcLight. As Blackwater and the Partnership were both affiliates of ArcLight as of April 15, 2013, these financial statements include the effect of Blackwater's operations starting as of the date of the establishment of common control. Therefore, these consolidated financial statements include Blackwater, which had a fiscal year end of March 31, 2013, and were presented from the period April 15, 2013 through December 31, 2013. Please see Note 20 "Reporting Segments" for financial information of Blackwater as presented in our Terminals segment.
	Transactions Between Entities Under Common Control
	We may enter into transactions with our General Partner and affiliates whereby we receive a contribution of midstream assets or subsidiaries in exchange for consideration from the Partnership. We account for the net assets received using the historical book value of the asset or subsidiary being contributed or transferred as these are transactions between entities under common control. Our historical financial statements may be revised to include the results attributable to the assets contributed from our General Partner as if we owned such assets for all periods presented by the Partnership since the change in control of our General Partner, effective April 15, 2013.
	Consolidation policy
	Our consolidated financial statements include our accounts and those of our subsidiaries in which we have a controlling interest. We hold a 50% undivided interest in the Burns Point gas processing facility in which we are responsible for our proportionate share of the costs and expenses of the facility. Our consolidated financial statements reflect our proportionate share of the revenues, expenses, assets and liabilities of this undivided interest. In July 2012, the Partnership acquired an 87.4% undivided interest in the Chatom Processing and Fractionation facility (the "Chatom System"). In October 2013, the Partnership acquired an additional 4.8% undivided interest in the Chatom System. Our consolidated financial statements reflect the accounts of the Chatom System since acquisition. The interests in the Chatom System held by non-affiliated working interest owners are reflected as noncontrolling interests in the Partnership's consolidated financial statements.
	Use of estimates
	When preparing financial statements in conformity with GAAP, management must make estimates and assumptions based on information available at the time. These estimates and assumptions affect the reported amounts of assets, liabilities, revenues and expenses, as well as the disclosures of contingent assets and liabilities as of the date of the financial statements. Estimates and judgments are based on information available at the time such estimates and judgments are made. Adjustments made with respect to the use of these estimates and judgments often relate to information not previously available. Uncertainties with respect to such estimates and judgments are inherent in the preparation of financial statements. Estimates and judgments are used in, among other things, (i) estimating unbilled revenues, product purchases and operating and general and administrative costs, (ii) developing fair value assumptions, including estimates of future cash flows and discount rates, (iii) analyzing long-lived assets, goodwill and intangible assets for possible impairment, (iv) estimating the useful lives of assets and (v) determining amounts to accrue for contingencies, guarantees and indemnifications. Actual results, therefore, could differ materially from estimated amounts.
	Cash and cash equivalents
	We consider all highly liquid investments with an original maturity of three months or less at the date of purchase to be cash equivalents. The carrying value of cash and cash equivalents approximates fair value because of the short term to maturity of these investments.
	Allowance for doubtful accounts
	We establish provisions for losses on accounts receivable when we determine that we will not collect all or part of an outstanding balance. Collectability is reviewed regularly and an allowance is established or adjusted, as necessary, using the specific identification method. As of December 31, 2013 and 2012, the Partnership recorded no allowances for losses on accounts receivable.
	Inventory
	Inventory includes NGL product inventory. The Partnership records all product inventories at the lower of cost or market (“LCM”), which is determined on a weighted average basis and included within Other current assets on the consolidated balance sheets. For the years ended December 31, 2013 and 2012, we recorded no lower-of-cost-or-market write-downs on our NGL inventory.
	Operational balancing agreements and natural gas imbalances
	To facilitate deliveries of natural gas and provide for operational flexibility, we have operational balancing agreements in place with other interconnecting pipelines. These agreements ensure that the volume of natural gas a shipper schedules for transportation between two interconnecting pipelines equals the volume actually delivered. If natural gas moves between pipelines in volumes that are more or less than the volumes the shipper previously scheduled, a natural gas imbalance is created. The imbalances are settled through periodic cash payments or repaid in-kind through future receipt or delivery of natural gas. Natural gas imbalances are recorded as gas imbalances and classified within other current assets or other current liabilities on our consolidated balance sheets based on the market value.
	Derivative financial instruments
	Our net income and cash flows are subject to volatility stemming from changes in interest rates on our variable rate debt, commodity prices and fractionation margins (the relative difference between the price we receive from NGL sales and the corresponding cost of natural gas purchases). In an effort to manage the risks to unitholders, we use a variety of derivative financial instruments including swaps, collars and interest rate caps to create offsetting positions to specific commodity or interest rate exposures. In accordance with the authoritative accounting guidance, we record all derivative financial instruments in our consolidated balance sheets at fair market value. We record the fair market value of our derivative financial instruments in the consolidated balance sheet as current and long-term assets or liabilities on a net basis by counterparty. We record changes in the fair value of our derivative financial instruments in our consolidated statements of operations as follows:
	•	Commodity-based derivatives: “Total revenue”
	•	Corporate interest rate derivatives: “Interest expense”
	Our formal hedging program provides a control structure and governance for our hedging activities specific to identified risks and time periods, which are subject to the approval and monitoring by the board of directors of our general partner. We employ derivative financial instruments in connection with an underlying asset, liability or anticipated transaction, and we do not use derivative financial instruments for speculative or trading purposes.
	The price assumptions we use to value our derivative financial instruments can affect net income for each period. We use published market price information where available, or quotations from over-the-counter, or OTC, market makers to find executable bids and offers. The valuations also reflect the potential impact of conditions, including credit risk of our counterparties. The amounts reported in our consolidated financial statements change quarterly as these valuations are revised to reflect actual results, changes in market conditions or other factors, many of which are beyond our control.
	Our earnings are affected by use of mark-to-market method of accounting as required under GAAP for derivative financial instruments. The use of mark-to-market accounting for derivative financial instruments can cause noncash earnings volatility resulting from changes in the underlying indices, primarily commodity prices.
	Fair value measurements
	We apply the authoritative accounting provisions for measuring fair value of our derivative instruments and disclosures associated with our outstanding indebtedness. We define fair value as an exit price representing the expected amount we would receive when selling an asset or pay to transfer a liability in an orderly transaction with market participants at the measurement date.
	We use various assumptions and methods in estimating the fair values of our financial instruments. The carrying amounts of cash and cash equivalents, accounts receivable and accounts payable approximated their fair value due to the short-term maturity of these instruments. The carrying amount of our various credit facilities approximate fair value, because the interest rates on these facilities are variable.
	We employ a hierarchy which prioritizes the inputs we use to measure recurring fair value into three distinct categories based upon whether such inputs are observable in active markets or unobservable. We classify assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our methodology for categorizing assets and liabilities that are measured at fair value pursuant to this hierarchy gives the highest priority to unadjusted quoted prices in active markets and the lowest level to unobservable inputs as outlined below:
	•	Level 1 – Inputs represent unadjusted quoted prices in active markets for identical assets or liabilities;
	•	Level 2 – Inputs include quoted prices for similar assets and liabilities in active markets that are either directly or indirectly observable; and
	•	Level 3 – Inputs are unobservable and considered significant to fair value measurement.
	We utilize a mid-market pricing convention, or the “market approach”, for valuation for assigning fair value to our derivative assets and liabilities. Our credit exposure for over-the-counter derivatives is directly with our counterparty and continues until the maturity or termination of the contracts. As appropriate, valuations are adjusted for various factors such as credit and liquidity considerations.
	Property, plant and equipment
	We capitalize expenditures related to property, plant and equipment that have a useful life greater than one year for (1) assets purchased or constructed; (2) existing assets that are replaced, improved, or the useful lives of which have been extended; and (3) all land, regardless of cost. Maintenance and repair costs, including any planned major maintenance activities, are expensed as incurred.
	We record property, plant, and equipment at its original cost, which we depreciate on a straight-line basis over its estimated useful life. Our determination of the useful lives of property, plant and equipment requires us to make various assumptions, including the supply of and demand for hydrocarbons in the markets served by our assets, normal wear and tear of the facilities, and the extent and frequency of maintenance programs. We record depreciation using the group method of depreciation, which is commonly used by pipelines, utilities and similar assets.
	Impairment of long lived Assets
	We evaluate the recoverability of our property, plant and equipment when events or circumstances such as economic obsolescence, business climate, legal and other factors indicate we may not recover the carrying amount of the assets. We continually monitor our business, the market, and business environment to identify indicators that could suggest an asset may not be recoverable. We evaluate the asset for recoverability by estimating the undiscounted future cash flows expected to be derived from operating the asset as a going concern. These cash flow estimates require us to make projections and assumptions for many years into the future for pricing, demand, competition, operating cost, contract renewals, and other factors. We recognize an impairment loss when the carrying amount of the asset exceeds its fair value as determined by quoted market prices in active markets or present value techniques. The determination of the fair value using present value techniques requires us to make projections and assumptions regarding future cash flows and weighted average cost of capital. Any changes we make to these projections and assumptions could result in significant revisions to our evaluation of the recoverability of our property, plant and equipment and the recognition of an impairment loss in our consolidated statements of income. We recorded impairments of long-lived assets of $18.2 million for the year ended December 31, 2013. No impairment losses were recognized during the years ended December 31, 2012 and 2011.
	Goodwill and intangible assets
	We record goodwill as the excess of the cost of an acquisition over the fair value of the net assets of the acquired business. Goodwill is not amortized but is reviewed for impairment at least annually or more frequently if an event or change in circumstance indicates that an impairment may have occurred. We first assess qualitative factors to evaluate whether it is more likely than not that an impairment has occurred and it is therefore necessary to perform the two-step goodwill impairment test. If the two-step goodwill impairment test indicates that the goodwill is impaired, an impairment loss is recorded.
	We record the estimated fair value of acquired customer contracts as intangible assets. The intangible assets are amortized over the remaining periods of the customer contracts, which range between 5 months and thirty-five months.
	Debt issuance costs
	Costs incurred in connection with the issuance of long-term debt are deferred and charged to interest expense over the term of the related debt. Gains or losses on debt repurchase and debt extinguishment include any associated unamortized debt issue costs.
Asset retirement obligations (“AROs”)
AROs are legal obligations associated with the retirement of tangible long-lived assets that result from the asset’s acquisition, construction, development and/or normal operation. An ARO is initially measured at its estimated fair value. Upon initial recognition of an ARO, we record an increase to the carrying amount of the related long-lived asset and an offsetting ARO liability. We depreciate the capitalized ARO using the straight-line method over the period during which the related long-lived asset is expected to provide benefits. After the initial period of ARO recognition, we revise the ARO to reflect the passage of time or revisions to the amount of estimated cash flows or their timing.
Commitments, contingencies and environmental liabilities
We expense or capitalize, as appropriate, expenditures for ongoing compliance with environmental regulations that relate to past or current operations. We expense amounts we incur from the remediation of existing environmental contamination caused by past operations that do not benefit future period by preventing or eliminating future contamination. We record liabilities for environmental matters when assessments indicate that remediation efforts are probable and the costs can be reasonably estimated. Estimates of environmental liabilities are based on currently available facts, existing technology and presently enacted laws and regulation taking into consideration the likely effects of inflation and other factors. These amounts also take into account our prior experience in remediating contaminated sites, other companies’ clean-up experience and data released by government organizations. Our estimates are subject to revision in future periods based on actual cost or new information. We evaluate recoveries from insurance coverage separately from the liability and, when recovery is probable, we record an asset separately from the associated liability in our consolidated financial statements.
We recognize liabilities for other commitments and contingencies when, after fully analyzing the available information, we determine it is either probable that an asset has been impaired or that a liability has been incurred and the amount of impairment or loss can be reasonably estimated. When a range of probable loss can be estimated, we accrue the most likely amount or if no amount is more likely than another, we accrue the minimum of the range of probable loss. We expense legal costs associated with loss contingencies as such costs are incurred.
We have legal obligations requiring us to decommission our offshore pipeline systems at retirement. In certain rate jurisdictions, we are permitted to include annual charges for removal costs in the regulated cost of service rates we charge our customers. Additionally, legal obligations exist for a minority of our offshore right-of-way agreements due to requirements or landowner options to compel us to remove the pipe at final abandonment. Sufficient data exists with certain onshore pipeline systems to reasonably estimate the cost of abandoning or retiring a pipeline system. However, in some cases, there is insufficient information to reasonably determine the timing and/or method of settlement of estimating the fair value of the asset retirement obligation. In these cases, the asset retirement obligation cost is considered indeterminate because there is no data or information that can be derived from past practice, industry practice, management’s experience, or the asset’s estimated economic life. The useful lives of most pipeline systems are primarily derived from available supply resources and ultimate consumption of those resources by end users. Variables can affect the remaining lives of the assets which preclude us from making a reasonable estimate of the asset retirement obligation. Indeterminate asset retirement obligation costs will be recognized in the period in which sufficient information exists to reasonably estimate potential settlement dates and methods.
Convertible preferred units
We record the issuance of our Series A Preferred Units at fair value and separately classify these units on our balance sheet in between total liabilities and partners’ capital, frequently called “mezzanine equity” as the ability to exercise these units are outside of the Partnership’s control and contain no beneficial conversion features pursuant to Accounting Standards Codification ("ASC")470-20, Debt with Conversion and Other Options. These units are classified as participating securities and are included in our calculation of net income (loss) per limited and general partner unit using the two-class method.
Noncontrolling interest
Noncontrolling interest represents the noncontrolling interest holders' proportionate share of the equity of the Chatom system. Noncontrolling interest is adjusted for the noncontrolling interest holders' proportionate share of the earnings or losses. Management reports noncontrolling interest in the Chatom system in the financial statements pursuant to paragraph ASC No. 810-10-65-1. The 7.8% noncontrolling interest is held by non-affiliated working interest owners.
Revenue recognition and the estimation of revenues and cost of purchases
We recognize revenue when all of the following criteria are met: (i) persuasive evidence of an exchange arrangement exists, (ii) delivery has occurred or services have been rendered, (iii) the price is fixed or determinable, and (iv) collectability is reasonably assured. We record revenue and cost of product sold on a gross basis for those transactions where we act as the principal and take title to natural gas, natural gas liquids ("NGLs") or condensates that are purchased for resale. When our customers pay us a fee for providing a service such as gathering, treating, transportation or storage, we record those fees separately in revenues. We have the following arrangements:
Fee-based
Under these arrangements, we generally are paid a fixed fee for gathering and transporting natural gas. Fee-based revenues, which are included in sales of natural gas, NGLs and condensate, are recorded when services have been provided, and collectability of the revenue is reasonably assured.
Percent-of-proceeds, or POP
Under these arrangements, we generally gather raw natural gas from producers at the wellhead or other supply points, transport it through our gathering system, process it and sell the residue natural gas and NGLs at market prices. Where we provide processing services at the processing plants that we own, or obtain processing service for our own account under our own elective processing arrangements we typically retain and sell a percentage of the residue natural gas and resulting NGLs. We recognize percent-of-proceeds contract revenue, which is included in sales of natural gas, NGLs and condensate, when the natural gas, NGLs or condensate is sold to a purchaser at a fixed or determinable price, delivery has occurred and title has transferred, and collectability of the revenue is reasonably assured.
Fixed-margin
Under these arrangements, we purchase natural gas from producers or suppliers at receipt points on our systems at an index price less a fixed transportation fee and simultaneously sell an identical volume of natural gas at delivery points on our systems at the same, undiscounted index price. We recognize revenue from fixed-margin contracts, which is included in sales of natural gas, NGLs and condensate, when the natural gas is sold to a purchaser at a fixed or determinable price, delivery has occurred and title has transferred and collectability of the revenue is reasonably assured.
Firm transportation
Under arrangements to provide firm transportation service, we are obligated to transport natural gas nominated by the shipper up to the maximum daily quantity specified in the contract. In exchange for that obligation on our part, the shipper pays a specified reservation charge, whether or not they utilize the capacity. In most cases, the shipper also pays a variable-use charge with respect to quantities actually transported by us. Firm transportation revenue is recorded when products are delivered, services have been provided and collectability of the revenue is reasonably assured.
Interruptible transportation
Under arrangements to provide interruptible transportation service, we are only obligated to transport natural gas nominated by the shipper to the extent we have available capacity. For this service the shipper pays no reservation charge but pays a variable-use charge for quantities actually shipped. Interruptible transportation revenue is recorded when products are delivered, services have been provided and collectability of revenue is reasonably assured.
Interest in the Burns Point Plant
We account for our interest in the Burns Point Plant using the proportionate consolidation method. Under this method, we include in our consolidated statement of operations our value of plant revenues taken in-kind and plant expenses reimbursed to the operator.
Terminal revenue and services
Revenues for our terminals include storage tank lease fees, whereby a customer agrees to pay for a certain amount of tank storage over a certain period of time; and throughput fees, whereby a customer pays a fee based on volumes moving through the terminal. At our terminals, we also offer and provide packaging, blending, handling, filtering and certain other ancillary services. Revenue from firm storage contracts is recognized ratably, which is typically monthly, over the term of the lease. Occasionally, customers pay for tank lease fees in advance. Fees received in advance are deferred until the period they are earned. Revenue from throughput fees and ancillary fees are recognized as services are provided to the customer and when the fees are realizable.
Unit-based employee compensation
We award unit-based compensation to management, non-management employees and directors in the form of phantom units, which are deemed to be equity awards. Compensation expense on phantom units is measured by the fair value of the award at the date of grant as determined by management. Compensation expense is recognized in equity compensation expense over the requisite service period of each award. See Note 15 "Long-Term Incentive Plan".
Income taxes
The Partnership is not a taxable entity for U.S. federal income tax purposes or for the majority of states that impose an income tax. Taxes on our net income generally are borne by our unitholders through the allocation of taxable income. However, Blackwater is a taxable entity. We account for income taxes using an asset and liability approach for financial accounting and reporting of income taxes. If it is more than likely that a deferred tax asset will not be realized, a valuation allowance is recognized.
Certain tax expense results from the enactment of state income tax laws by the State of Texas that apply to entities organized as partnerships and is included in selling, general and administrative expenses in the consolidated statements of operations. The Texas margin tax is computed on our modified gross margin and was not significant for each of the years ended December 31, 2013, 2012 and 2011.
Net income for financial statement purposes may differ significantly from taxable income allocable to unitholders as a result of differences between the tax basis and financial reporting basis of assets and liabilities and the taxable income allocation requirement under our partnership agreement. The aggregate difference in the basis of our net assets for financial and tax reporting purposes cannot be readily determined because information regarding each partner’s tax attributes in us is not available.
Comprehensive income (loss)
The Partnership’s other comprehensive income (loss) is comprised of adjustments to other post-retirement plan assets and liabilities. See Note 16 "Post-Employment Benefits".
Limited partners’ net income (loss) per unit
We compute limited partners’ net income (loss) per unit by dividing our limited partners’ interest in net income (loss) by the weighted average number of units outstanding during the period. The overall computation, presentation and disclosure of our limited partners’ net income (loss) per unit are made in accordance with the FASB Accounting Standards Codification (ASC) Topic 260 “Earnings per Share”.
Accounting for regulated operations
Certain of our natural gas pipelines are subject to regulations by FERC. FERC exercises statutory authority over matters such as construction, transportation rates we charge and our underlying accounting practices and ratemaking agreements with customers. Accordingly, we record costs that are allowed in the ratemaking process in a period different from the period in which the costs would be charged to expense by a non-regulated entity. Also, we record assets and liabilities that result from the regulated ratemaking process that would be recorded under GAAP for our regulated entities. As of December 31, 2013 and 2012, we had no such material regulatory assets or liabilities.
Recent accounting pronouncements
In January 2013, the FASB issued Accounting Standards Update ("ASU") No. 2013-01, Balance Sheet (Topic 210): Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities, which clarifies that ASU 2011-11, Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities, applies to financial instruments or derivative transactions accounted for under ASC 815. The amendments require disclosures to present both gross and net amounts of derivative assets and liabilities that are subject to master netting arrangements with counterparties. We currently present our net derivative assets and liabilities on our statement of financial position. We have provided additional disclosures regarding the gross amounts of derivative assets and liabilities in Note 6 "Derivatives" in accordance with these new standards updates.
In February 2013, the FASB issued ASU No. 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income ("AOCI"), which requires entities to present either in a single note or parenthetically on the face of the financial statements (i) the amount of significant items reclassified from each component of AOCI and (ii) the income statement line items affected by the reclassifications. We adopted this guidance during the first quarter of 2013; it did not have a material impact on our condensed consolidated financial statements as there are currently no items reclassified from AOCI.
In July 2013, the FASB issued ASC No. 2013-11, Income Taxes (Topic 740): Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists (a consensus of the FASB Emerging Issues Task Force). This guidance was issued related to the presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss or a tax credit carryforward exists. The updated guidance requires an entity to net its unrecognized tax benefits against the deferred tax assets for all same jurisdiction net operating loss carryforward, a similar tax loss, or tax credit carryforwards. A gross presentation will be required only if such carryforwards are not available or would not be used by the entity to settle any additional income taxes resulting from disallowance of the uncertain tax position. The update is effective prospectively for the Partnership’s fiscal year beginning January 1, 2014 and we are currently evaluating the financial impact.

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Acquisitions	'
	Acquisitions
	Blackwater Terminals
	Effective December 17, 2013, we acquired Blackwater, consisting of AL Blackwater, LLC ("ALB"), a Delaware limited liability company, Blackwater Midstream Holdings LLC, a Delaware limited liability company and a majority owned subsidiary of ALB, and Blackwater Merger Sub, LLC, a Delaware limited liability company and wholly owned subsidiary of the Partnership. Blackwater operates 1.3 million barrels of storage capacity across four marine terminal sites located in Westwego, Louisiana; Brunswick, Georgia; Harvey, Louisiana; and Salisbury, Maryland.
	The Partnership distributed consideration of $63.9 million, of which $27.7 million was accounted for as a cash distribution to the general partner. The consideration also included 125,500 limited partner units which were accounted for as a non-cash distribution to the general partner at a fair value of $3.1 million. The fair value of the units issued was determined using level one inputs based upon the Partnership's closing unit price on December 17, 2013.
	The remaining consideration was utilized to settle all of the Blackwater's outstanding debt at December 17, 2013.
	The acquisition of Blackwater represents a transaction between entities under common control and a change in reporting entity. Transfers of net assets or exchanges of shares between entities under common control are accounted for as if the transfer occurred at the beginning of the period or date of common control. Therefore, net assets received were recorded at their historical book value of $22.7 million as of the date common control was established, which is April 15, 2013.
	On July 10, 2013, Blackwater acquired and purchased from Chemtura Corporation approximately 56 acres of property and improvements located in Harvey, Louisiana for $2.5 million (the "Harvey assets"). The land is adjacent to the Mississippi River and the assets include dormant storage tanks, unoccupied buildings, a barge dock and other improvements.
	The Harvey assets when purchased did not include any employees, customer contracts, permits, licenses, offices, procedures, systems, or processes that had the ability to produce outputs; thus this asset purchase did not meet the definition of a business under the accounting guidance.
	For the period from April 15, 2013 to December 31, 2013, Blackwater contributed $9.8 million of revenue and $0.8 million of net loss attributable to the Partnership's Terminals segment, which are included in the consolidated statement of operations.
	High Point System
	Effective April 15, 2013, our General Partner contributed the High Point System, consisting of 100% of the limited liability company interests in High Point Gas Transmission, LLC, and High Point Gas Gathering, LLC. The High Point System consists of approximately 700 miles of natural gas and liquids pipeline assets located in southeast Louisiana, in the Plaquemines and St. Bernard parishes, and the shallow water and deep shelf Gulf of Mexico, including the Mississippi Canyon, Viosca Knoll, West Delta, Main Pass, South Pass and Breton Sound zones. Natural gas is collected at more than 75 receipt points that connect hundreds of wells with an emphasis on oil and liquids-rich reservoirs.
	The High Point System, along with $15.0 million in cash, was contributed to us by HPIP in exchange for 5,142,857 Series A Units. Of the cash consideration paid by HPIP, approximately $2.5 million was used to pay certain transaction expenses of HPIP, and the remaining approximately $12.5 million was used to repay borrowings outstanding under the Partnership's credit facility in connection with the Fourth Amendment. The contribution of the High Point System occurred concurrently with HPIP's acquisition of 90% of our General Partner and all of our subordinated units, which resulted in HPIP gaining control of our General Partner and a majority of our outstanding limited partner interests.
	The fair value of the Series A Units on April 15, 2013, was $17.50 per unit, or a total of $90.0 million, and was issued by the Partnership in exchange for net cash of approximately $12.5 million and net assets of $61.9 million contributed to the Partnership by our General Partner. The contribution of net assets of the High Point System was accounted for as a transaction between entities under common control whereby the High Point System was recorded at historical book value. As such, the value of the Series A Units in excess of the net assets contributed by our General Partner amounted to $15.6 million and was allocated pro-rata to our General Partner and existing limited partners' interest based on their ownership interests.
	The contribution is being treated as a transaction between entities under common control, under which the net assets received are recorded at their historical book value as of date of transfer. The following table presents the carrying value of the identified assets received and liabilities assumed at the acquisition date (in thousands):
	Cash and cash equivalents	$	1,935
	Accounts receivable	3,629
	Unbilled revenue	1,446
	Other current assets	2,049
	Property, plant and equipment, net	82,615
	Other assets	1,000
	Accounts payable	(11		)
	Accrued expenses and other current liabilities	(4,077		)
	Current portion of long-term debt	(893		)
	Asset retirement obligation liability	(25,763		)
	Total identifiable net assets	$	61,930
	Subsequent to the contribution, for the year ended December 31, 2013, the High Point System contributed $30.4 million of revenue and $7.2 million of net income attributable to the Partnership's Transmission segment, which are included in the consolidated statement of operations.
	Chatom Gathering, Processing and Fractionation Plant
	Effective July 1, 2012, we acquired an 87.4% undivided interest in the Chatom system from affiliates of Quantum Resources Management, LLC. The acquisition fair value consideration of $51.4 million includes a credit associated with the cash flow the Chatom system generated between January 1, 2012, and the effective date of July 1, 2012. The consideration paid by the Partnership consisted of cash, which was funded under borrowings under our revolving credit facility.
	The Chatom system is located in Washington County, Alabama, approximately 15 miles from our Bazor Ridge processing plant in Wayne County, Mississippi, and consists of a 25 MMcf/d cryogenic processing plant, a 1,900 Bbl/d fractionation unit, a 160 long-ton per day sulfur recovery unit, and a 29 mile gas gathering system. We believe the fractionating services provide flexibility to the Partnership's product and service offerings.
	The following table presents the fair value of consideration transferred to acquire the Chatom system and the amounts of identified assets acquired and liabilities assumed at the acquisition date, as well as the fair value of the 12.6% noncontrolling interest in the Chatom system at the acquisition date (in thousands):
	Cash consideration:	$	51,377
	Recognized amounts of identifiable assets acquired and liabilities assumed:
	Unbilled revenue	$	4,535
	Property, plant and equipment	58,279
	Asset retirement cost	452
	Accounts payable	(399		)
	Accrued gas purchases	(3,631		)
	Asset retirement obligations	(452		)
	Noncontrolling interest	(7,407		)
	Total identifiable net assets:	$	51,377
	The fair value of the property, plant and equipment and noncontrolling interests were estimated by applying a combination of the market and income approaches. These fair value measurements are based on significant inputs not observable in the market and thus represents a Level 3 measurement as defined by ASC 820. Primarily using the income approach, the fair value estimates are based on (i) an assumed cost of capital of 9.25%, (ii) an assumed terminal value based on the present value of estimated EBITDA, (iii) an inflationary cost increase of 2.5%, (iv) forward market prices as of July 2012 for natural gas and crude oil, (v) a Federal tax rate of 35% and a state tax rate of 6.5%, and (vi) an increase in processed and fractionated volumes in 2013, declining thereafter. Working capital was estimated using net realizable value. Accrued revenue was deemed to be fully collectible at July 1, 2012.
	During the fourth quarter of 2013 we offered to purchase the noncontrolling interest in Chatom from all holders of the noncontrolling interest. As of December 31, 2013, 38% of the noncontrolling interest was purchased by us (a 4.8% overall interest), increasing our total ownership to 92.2% and reducing the noncontrolling interest to 7.8%.
	Subsequent to the initial 87.4% acquisition, our undivided interest in the Chatom system contributed $25.4 million of revenue and $1.8 million of net income attributable to the Partnership, which are included in the consolidated statement of operations for the year ended December 31, 2012. For the year ended December 31, 2013, our interest in the Chatom system contributed $56.5 million of revenue and $5.4 million of net income attributable to the Partnership.
	The following table presents unaudited pro forma consolidated information of the Partnership, adjusted for the acquisition of the Chatom system, as if the acquisition had occurred on January 1, 2011 (in thousands, except per unit amounts):
		Year Ended December 31,
		2012			2011
	Revenue	$	246,342		$	296,387
	Net loss	(4,319		)	(10,411		)
	Limited partners’ net loss per unit	(0.49		)	(1.53		)
	These amounts have been calculated after applying the Partnership's accounting policies and adjusting the results to reflect (i) additional depreciation and amortization that would have been charged assuming fair value adjustments to property, plant and equipment, and (ii) recording pro forma interest expense on debt that would have been incurred to acquire the Chatom system as of January 1, 2012 and 2011, respectively. The unaudited pro forma adjustments are based on available information and certain assumptions we believe are reasonable.
	Burns Point Plant Interest
	On December 1, 2011, we acquired a 50% undivided interest in the Burns Point Plant from Marathon Oil Company (“Marathon”) for total cash consideration of $35.5 million. No liabilities of Marathon were assumed. The purchase was effective November 1, 2011 with our assumption of insurable risks, operating liabilities and entitlement to in-kind revenues as of that date. The remaining 50% undivided interest is owned by the Burns Point Plant operator, Enterprise Gas Processing, LLC (“Enterprise”). The Burns Point Plant, which is an unincorporated venture, is governed by a construction and operating agreement (“Agreement”).
	The fair value of the assets calculated under the market participant approach was in excess of cash consideration paid resulting in a $0.6 million bargain purchase gain.
	The following table presents unaudited pro forma consolidated information of the Partnership, adjusted for the acquisition of the Interest in the Plant, as if the acquisition had occurred on January 1, 2011 (in thousands, except per unit amounts):
		Year Ended
		31-Dec-11
	Revenue	$	249,908
	Net loss	(11,741		)
	Limited partners’ net loss per unit	(1.65		)
	These amounts have been calculated after applying the Partnership's accounting policies and adjusting the results to reflect (i) additional depreciation and amortization that would have been charged assuming fair value adjustments to property, plant and equipment, (ii) recording pro forma interest expense on debt that would have been incurred to acquire our interest in the Plant, and (iii) elimination of the bargain purchase gain as of January 1, 2011. The unaudited pro forma adjustments are based on available information and certain assumptions we believe are reasonable.
	The unaudited pro forma consolidated financial information is for informational purposes only and is not intended to represent or be indicative of the consolidated results of operations or financial position that we would have reported had these acquisitions been completed on the date indicated and should not be taken as representative of its future consolidated results of operations or financial position. Further, the unaudited pro forma consolidated statement of operations is not indicative of the operations going forward because it necessarily excludes various operating expenses.

Discontinued_Operations_Notes

Discontinued Operations (Notes)	12 Months Ended
	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	'
	Discontinued Operations
	We classify long-lived assets to be disposed of through sales that meet specific criteria as held for sale. We cease depreciating those assets effective on the date the asset is classified as held for sale. We record those assets at the lower of their carrying value or the estimated fair value less the cost to sell. Until the assets are disposed of, an estimate of the fair value is re-determined when related events or circumstances change.
	During the second quarter of 2013, the board of directors of our General Partner approved a plan to sell certain non-strategic gathering and processing assets which meet specific criteria, qualifying them as held for sale. During the year ended December 31, 2013, certain gathering and processing assets were written down by $1.8 million to the estimated fair value less cost to sell. These fair value measurements are based on significant inputs not observable in the market and thus represent a Level 3 measurement as defined by ASC 820. Primarily using the income approach, the fair value estimates are based on (i) present value of estimated EBITDA, (ii) an assumed discount rate of 10%, and iii) a decline in throughput volumes of 2.5% in 2013 and thereafter.
	The net book value of the non-strategic gathering and processing assets classified as held for sale comprise $1.2 million of Current assets held for sale, $0.3 million of Noncurrent assets held for sale, net, and $1.1 million of Current liabilities held for sale on the consolidated balance sheet as of December 31, 2013.
	As part of the Blackwater Acquisition, we acquired long-lived terminal assets classified as held for sale. As of December 31, 2013, certain long-lived terminal assets were written down by $0.6 million to the estimated fair value less cost to sell. These fair value measurements are based on significant inputs not observable in the market and thus represent a Level 3 measurement as defined by ASC 820. Using a combination of the market and cost approaches, the fair value estimates are based on (i) sales price per barrel of recent transactions as well as replacement cost estimates that include an economic obsolescence factor.
	The net book value of the assets and liabilities attributable to the terminal assets are presented separately on the consolidated balance sheet and comprise $0.1 million of Current assets held for sale, $1.6 million of Noncurrent assets held for sale, net, less than $0.1 million of Current liabilities held for sale and all of the Noncurrent liabilities held for sale, net as of December 31, 2013.
	As a result of the planned divestiture of these non-strategic midstream assets, we have accounted for these disposal groups as discontinued operations within our Gathering and Processing and Terminal segments. Accordingly, we reclassified and excluded the disposal groups' results of operations from our results of continuing operations and reported the disposal groups' results of operations as (Loss) income from operations of disposal groups, net of tax in our accompanying consolidated statement of operations for all periods presented. We did not, however, elect to present separately the operating, investing and financing cash flows related to the disposal groups in our accompanying consolidated statement of cash flows as this activity was immaterial for all periods presented. The following table presents the revenue, expense and (loss) gain from operations of disposal groups associated with the assets classified as held for sale for the years ended December 31, 2013, 2012, and 2011 (in thousands, except per unit amounts):
		Year Ended December 31,
		2013			2012			2011
	Revenue	$	14,845		$	12,343		$	17,024
	Expense	(14,964		)	(12,024		)	(16,692		)
	Impairment	(2,400		)	—			—
	Loss on sale of assets	(75		)	—			—
	Income tax benefit	339			—			—
	(Loss) income from operations of disposal groups, net of tax	$	(2,255	)	$	319		$	332
	Limited partners' net (loss) income per unit from discontinued operations (basic and diluted)	$	(0.24	)	$	0.03		$	0.04

Concentration_of_Credit_Risk_a

Concentration of Credit Risk and Trade Accounts Receivable	12 Months Ended
	Dec. 31, 2013
Receivables [Abstract]	'
Concentration Risk Disclosure [Text Block]	'
	Concentration of Credit Risk and Trade Accounts Receivable
	Our primary market areas are located in the United States along the Gulf Coast and in the Southeast. We have as concentration of trade receivable balances due from companies engaged in the production, trading, distribution and marketing of natural gas and NGL products. These concentrations of customers may affect our overall credit risk in that the customers may be similarly affected by changes in economic, regulatory or other factors. Our customers’ historical financial and operating information is analyzed prior to extending credit. We manage our exposure to credit risk through credit analysis, credit approvals, credit limits and monitoring procedures, and for certain transactions, we may request letters of credit, prepayments or guarantees. We maintain allowances for potentially uncollectible accounts receivable; however, for the years ended December 31, 2013, 2012 and 2011, no allowances on or write-offs of accounts receivable were recorded.
	The following table summarizes the percentage of revenue earned from those customers that exceed 10% or greater of the Partnership's consolidated revenue in the consolidated statement of operations for the each of the periods presented below:
		Year Ended December 31,
		2013		2012		2011
	Customer A	28	%	30	%	41	%
	Customer B	13	%	—		—
	Customer C	12	%	13	%	15	%
	Customer D	10	%	14	%	18	%
	Other	37	%	43	%	26	%
	Total	100	%	100	%	100	%

Other_Current_Assets

Other Current Assets	12 Months Ended
	Dec. 31, 2013
Other Current Assets [Abstract]	'
Other Current Assets	'
	Other Current Assets
	Other current assets consists of the following (in thousands):
		December 31,
		2013		2012
	Prepaid insurance	$	3,166	$	458
	Other current assets	4,331		2,768
		$	7,497	$	3,226

Derivatives

Derivatives	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivatives	'
	Derivatives
	Commodity Derivatives
	To minimize the effect of commodity prices and maintain our cash flow and the economics of our development plans, we enter into commodity hedge contracts from time to time. The terms of the contracts depend on various factors, including management’s view of future commodity prices, acquisition economics on purchased assets and future financial commitments. This hedging program is designed to mitigate the effect of commodity price downturns while allowing us to participate in some commodity price upside. Management regularly monitors the commodity markets and financial commitments to determine if, when, and at what level commodity hedging is appropriate in accordance with policies that are established by the board of directors of our general partner. Currently, the commodity derivatives are in the form of swaps and collars. As of December 31, 2013, the aggregate notional volume of our commodity derivatives was 2.9 million gallons.
	We enter into commodity contracts with multiple counterparties. We may be required to post collateral with our counterparties in connection with our derivative positions. As of December 31, 2013, we have not posted collateral with our counterparties. The counterparties are not required to post collateral with us in connection with their derivative positions. Netting agreements are in place with our counterparties that permit us to offset our commodity derivative asset and liability positions.
	For accounting purposes, no derivative instruments were designated as hedging instruments and were instead accounted for under the mark-to-market method of accounting, with any changes in the fair value of the derivatives recorded in the consolidated balance sheets and through earnings, rather than being deferred until the anticipated transactions affect earnings. The use of mark-to-market accounting for financial instruments can cause non-cash earnings volatility due to changes in the underlying commodity price indices or interest rates.
	Interest Rate Swap
	We entered into an interest rate swap to manage the impact of the interest rate risk associated with our credit facility, effectively converting a portion of the cash flows related to our long-term variable rate debt into fixed rate cash flows. As of December 31, 2013, the notional amount of our interest rate swap was $100 million. The interest rate swap was entered into with a single counterparty and we were not required to post collateral.
	Weather Derivative
	In the second quarter of 2013, we entered into a weather derivative to mitigate the impact of potential unfavorable weather to our operations under which we could receive payments totaling up to $10 million in the event that a hurricane or hurricanes of certain strength pass through the area as identified in the derivative agreement. The weather derivative is being accounted for using the intrinsic value method, under which the fair value of the contract is zero and any amounts received are recognized as gains during the period received. The weather derivative was entered into with a single counterparty, and we were not required to post collateral. We paid a premium of approximately $1.1 million, which is recorded in Risk management assets on the consolidated balance sheet and is being amortized to Direct operating expenses on a straight-line basis over the term of the contract of 12 months. As of December 31, 2013, the unamortized amount of the risk management asset was approximately $0.5 million.
	As of December 31, 2013 and 2012, the value associated with our commodity derivatives, interest rate swap instrument and weather derivative were recorded in our consolidated balance sheets, under the captions as follows (in thousands):
		Gross Risk Management Assets						Gross Risk Management Liabilities						Net Risk Management Assets (Liabilities)
	Balance Sheet Classification	December 31, 2013			December 31, 2012			December 31, 2013			December 31, 2012			December 31, 2013			December 31, 2012
	Current	$	473		$	1,889		$	—		$	(920	)	$	473		$	969
	Noncurrent	—			—			—			—			—			—
	Total assets	$	473		$	1,889		$	—		$	(920	)	$	473		$	969
	Current	$	27		$	—		$	(450	)	$	—		$	(423	)	$	—
	Noncurrent	—			—			(101		)	—			(101		)	—
	Total liabilities	$	27		$	—		$	(551	)	$	—		$	(524	)	$	—
	For the years ended December 31, 2013, 2012 and 2011, the realized and unrealized gains (losses) associated with our commodity, interest rate and weather derivative instruments were recorded in our consolidated statements of operations, under the captions as follows (in thousands):
		Realized			Unrealized
	2013
	Gain (loss) on commodity derivatives	$	1,069		$	(1,041	)
	Interest expense	(207		)	(454		)
	Direct operating expenses	(662		)	—
	Total	$	200		$	(1,495	)
	2012
	Gain (loss) on commodity derivatives	$	2,408		$	992
	Total	$	2,408		$	992
	2011
	Gain (loss) on commodity derivatives	$	(1,911	)	$	(541	)
	Realized loss on early termination of commodity derivatives	(2,998		)	—
	Total	$	(4,909	)	$	(541	)

Fair_Value_Measurement

Fair Value Measurement	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurement	'
	Fair Value Measurement
	The authoritative guidance for fair value measurements establishes a three-tier fair value hierarchy, which prioritizes the inputs used to measure fair value. These tiers include:
	•	Level 1 – Inputs represent unadjusted quoted prices in active markets for identical assets or liabilities;
	•	Level 2 – Inputs include quoted prices for similar assets and liabilities in active markets that are either directly or indirectly observable; and
	•	Level 3 – Inputs are unobservable and considered significant to fair value measurement.
	A financial instrument’s categorization within the fair value hierarchy is based upon the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the classification of assets and liabilities within the fair value hierarchy.
	We believe the carrying amount of cash and cash equivalents approximates fair value because of the short-term maturity of these instruments. Our cash and cash equivalents would be classified as Level 1 under the fair value hierarchy.
	The recorded value of the amounts outstanding under the credit facility approximates its fair value, as interest rates are variable, based on prevailing market rates and the short-term nature of borrowings and repayments under the credit facility. Our existing revolving credit facility would be classified as Level 1 under the fair value hierarchy.
	The recorded amounts of impairments of long-lived assets utilize fair value measurements based on significant inputs not observable in the market and thus represent a Level 3 measurement. Primarily using the income approach, the fair value estimates are based on (i) present value of estimated EBITDA, (ii) an assumed discount rate and (iii) a rate of decline in throughput volumes.
	The fair value of all derivatives instruments is estimated using a market valuation methodology based upon forward commodity price curves, volatility curves as well as other relevant economic measures, if necessary. Discount factors may be utilized to extrapolate a forecast of future cash flows associated with long dated transactions or illiquid market points. The inputs are obtained from independent pricing services, and we have made no adjustments to the obtained prices.
	We have consistently applied these valuation techniques in all periods presented and believe we have obtained the most accurate information available for the types of derivatives contracts held. We will recognize transfers between levels at the end of the reporting period for which the transfer has occurred. We recognized transfers out of Level 3 into Level 2 as a result of changes in tenure and market points of certain contracts in the amount of $1.0 million for the year ended December 31, 2012. There were no such transfers for the year ended December 31, 2013.
	Fair Value of Financial Instruments
	The following table sets forth by level within the fair value hierarchy, our commodity derivative instruments and interest rate swap, included as part of Risk management assets and Risk management liabilities within the balance sheet, that were measured at fair value on a recurring basis as of December 31, 2013 and 2012 (in thousands):
		Carrying			Estimated Fair Value of the Asset (Liability)
		Amount			Level 1		Level 2			Level 3		Total
	Commodity derivative instruments, net
	31-Dec-13	$	(70	)	$	—	$	(70	)	$	—	$	(70	)
	31-Dec-12	969			—		969			—		969
	Interest rate swap
	31-Dec-13	$	(454	)	$	—	$	(454	)	$	—	$	(454	)
	31-Dec-12	—			—		—			—		—
	The unamortized portion of the premium paid to enter the weather derivative described in Note 6 "Derivatives", is included within Risk management assets on the balance sheet but is not included as part of the above table as it is recorded at amortized carrying cost, not fair value.

Property_Plant_and_Equipment_N

Property, Plant and Equipment, Net	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment, Net	'
	Property, Plant and Equipment
	Property, plant and equipment, net, as of December 31, 2013 and 2012, were as follows (in thousands):
		Useful Life	December 31,			December 31,
		(in years)	2013			2012
	Land	N/A	$	6,015		$	2,254
	Construction in progress	N/A	6,443			5,053
	Base gas	N/A	1,108			—
	Buildings and improvements	4 to 40	5,109			1,432
	Processing and treating plants	8 to 40	97,106			98,106
	Pipelines	5 to 40	239,826			163,447
	Compressors	4 to 20	11,793			8,957
	Dock	20 to 40	7,942			—
	Tanks, truck rack and piping	20 to 40	22,432			—
	Equipment	8 to 20	6,293			4,785
	Computer software	5	3,531			1,950
	Total property, plant and equipment		407,598			285,984
	Accumulated depreciation		(95,088		)	(62,165		)
	Property, plant and equipment, net		$	312,510		$	223,819
	Of the gross property, plant and equipment balances at December 31, 2013 and 2012 include $100.5 million and $26.1 million, respectively, were related to AlaTenn, Midla and High Point Gas Transmission, our FERC regulated interstate and intrastate assets.
	Capitalized interest was $0.2 million and zero for the years ended December 31, 2013 and 2012, respectively.
	Depreciation expense was $25.9 million and $21.4 million for the years ended December 31, 2013 and 2012, respectively.
	Asset Impairments
	During the second quarter of 2013, management determined to change its commercial approach towards certain non-strategic gathering and processing assets. As a result, an asset impairment charge of $15.2 million was recorded in the three months ended June 30, 2013. These fair value measurements are based on significant inputs not observable in the market and thus represent a Level 3 measurement as defined by ASC 820. Primarily using the income approach, the fair value estimates are based on (i) present value of estimated EBITDA, (ii) an assumed discount rate of 10%, and (iii) a decline in throughput volumes of 2.5% in 2013 and thereafter.
	During the second quarter of 2013, the board of directors of our General Partner approved a plan to sell certain non-strategic gathering and processing assets which meet specific criteria, qualifying them as held for sale. As a result, certain gathering and processing assets were written down by $1.8 million to the estimated fair value less cost to sell. As part of the Blackwater Acquisition, we acquired long-lived terminal assets classified as held for sale. As of December 31, 2013, certain long-lived terminal assets were written down by $0.6 million to the estimated fair value less cost to sell. See Note 3 "Discontinued Operations".
	During the first quarter of 2014, the board of directors of our General Partner gave approval to the management team to pursue the sale of certain gathering and processing assets for an amount less than the carrying value of the assets. As a result, these gathering and processing assets were written down by $3.0 million in the fourth quarter of 2013.
	Insurance proceeds
	Involuntary conversions result from the loss of an asset because of some unforeseen event (e.g., destruction due to hurricanes). Some of these events are insurable, thus resulting in a property damage insurance recovery. Amounts we receive from insurance carriers are net of any deductibles related to the covered event. During the year ended December 31, 2013, we collected $1.1 million of nonrefundable cash proceeds from our insurance carrier. During the first quarter of 2013, $0.5 million of nonrefundable cash proceeds were recognized as an offset to property, plant and equipment write-downs of $0.1 million and presented as $0.4 million under the caption Gain (loss) on involuntary conversion of property, plant and equipment. During the second quarter of 2013, $0.6 million of nonrefundable cash proceeds were associated with business interruption insurance and recorded to Revenue in the consolidated statement of operations.

Goodwill_and_Intangible_assets

Goodwill and Intangible assets (Notes)	12 Months Ended
	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]	'
Goodwill and Intangible Assets Disclosure [Text Block]	'
	Goodwill and Intangible Assets, Net
	Goodwill of $16.4 million was contributed to the Partnership as part of the Blackwater Acquisition. Goodwill is not amortized and is assessed for impairment annually or more frequently if an event or circumstance indicates that an impairment may have occurred. Goodwill was recorded as a result of the excess of the investment by ArcLight in Blackwater over the fair market value of the identifiable net assets and customer contracts acquired in 2012.
	Intangible assets, net, consist of customer contracts contributed to the Partnership as part of the Blackwater acquisition. The intangible assets are amortized on a straight-line basis over the economic lives of the customer contracts, currently ranging from 5 months to thirty-five months. Intangible assets, net, consist of the following as of December 31, 2013 (in thousands):
		December 31,
		2013
	Customer contracts	$	12,101
	Accumulated amortization	(8,419		)
	Intangible assets, net	$	3,682
	Amortization expense was $3.7 million for the period from April 15, 2013 to December 31, 2013.
	Future amortization of the intangible assets, net will be $2.7 million in 2014 and $1.0 million in 2015.

Accrued_Expenses_and_Other_Cur

Accrued Expenses and Other Current Liabilities	12 Months Ended
	Dec. 31, 2013
Payables and Accruals [Abstract]	'
Accounts Expenses and Other Current Liabilities	'
	Accrued Expenses and Other Current Liabilities
	Accrued expenses and other current liabilities were as follows (in thousands):
		December 31,
		2013		2012
	Accrued expenses	$	5,906	$	6,519
	Gas imbalances payable	4,305		971
	Other accrued expenses and other current liabilities	4,847		2,129
		$	15,058	$	9,619

Asset_Retirement_Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligation	'
	Asset Retirement Obligations
	We record a liability for the fair value of asset retirement obligations and conditional asset retirement obligations that we can reasonably estimate, on a discounted basis, in the period in which the liability is incurred. We collectively refer to asset retirement obligations and conditional asset retirement obligations as ARO.
	Certain assets related to our Transmission segment have regulatory obligations to perform remediation and, in some instances, dismantlement and removal activities when the assets are abandoned. These asset retirement obligations include varying levels of activity including disconnecting inactive assets from active assets, cleaning and purging assets, and in some cases, completely removing the assets and returning the land to its original state. These assets have been in existence for many years and with regular maintenance will continue to be in service for many years to come. It is not possible to predict when demand for these transmission services will cease, and we do not believe that such demand will cease for the foreseeable future. A portion of our regulatory obligations is related to assets that we plan to take out of service.
	No assets were legally restricted for purposes of settling our ARO liabilities during the years ended December 31, 2013 and 2012. The following table is a reconciliation of the asset retirement obligations (in thousands):
		Year Ended December 31,
		2013		2012
	Beginning asset retirement obligation	$	8,319	$	8,093
	Liabilities assumed	25,763		452
	Expenditures	—		(258		)
	Accretion expense	554		32
	Ending asset retirement obligation	$	34,636	$	8,319
	We are required to establish security against any potential secondary obligations relating to the abandonment of the certain transmission assets that may be imposed on the previous owner by applicable regulatory authorities. As such, we have a restricted cash account that is established, held and maintained by a third party that amounts to $3.0 million and is presented in Other assets, net in our consolidated balance sheet as of December 31, 2013.

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Long-Term Debt	'
	As of December 31, 2013, the Partnership's Credit Agreement (the "Credit Agreement") provides for a maximum borrowing equal to $200 million or subject to, among other restrictions, the requirement that our indebtedness not exceed 5.75 times adjusted consolidated EBITDA. We can elect to have loans under the our credit facility bear interest either at a Eurodollar-based rate plus a margin ranging from 1.50% to 3.75% depending on our total leverage ratio then in effect, or a base rate which is a fluctuating rate per annum equal to the highest of (a) the Federal Funds Rate plus 0.50%, (b) the rate of interest in effect for such day as publicly announced from time to time by Bank of America as its “prime rate”, or (c) the Eurodollar Rate plus 1.00% plus a margin ranging from 2.50% to 4.75% depending on the total leverage ratio then in effect. We also paid a commitment fee of 0.50% per annum on the undrawn portion of the revolving loan.
	Our obligations under the credit facility are secured by a first mortgage in favor of the lenders in our real property. Advances made under the credit facility are guaranteed on a senior unsecured basis by certain of our subsidiaries (“Guarantors”). These guarantees are full and unconditional and joint and several among the Guarantors. The terms of the new credit facility include covenants that restrict our ability to make cash distributions and acquisitions in some circumstances. The remaining principal balance of loans and any accrued and unpaid interest will be due and payable in full on the maturity date, August 1, 2016.
	The credit facility also contains customary representations and warranties (including those relating to organization and authorization, compliance with laws, absence of defaults, material agreements and litigation) and customary events of default (including those relating to monetary defaults, covenant defaults, cross defaults and bankruptcy events). The primary financial covenants contained in the credit facility are (i) a total consolidated leverage ratio test (not to exceed 5.75 times) and (ii) a minimum interest coverage ratio test (not less than 2.50).
	Please see Note 23 "Liquidity" for more details on our amendments to the Credit Agreement during the year ended December 31, 2013.
	On April 15, 2013, we repaid approximately $12.5 million in outstanding borrowings in connection with the ArcLight Transactions. On September 30, 2013, we received $12.5 million from HPIP which was used to repay outstanding borrowings under the credit agreement. Please see Note 13 "Partners' Capital" for more details.
	For the years ended December 31, 2013, 2012 and 2011, the weighted average interest rate on borrowings under our credit facilities was approximately 4.53%, 4.09%, and 6.71%, respectively.
	As of December 31, 2013 our consolidated total leverage was 3.70, which was in compliance with the consolidated total leverage ratio test in accordance with the leverage covenants as modified in the Fifth Amendment to the credit facility executed on December 17, 2013. As of December 31, 2013, we had approximately $130.7 million of outstanding borrowings under our credit facility and approximately $64.5 million of available borrowing capacity.
	Other debt
	Other debt represents insurance premium financing in the original amount of $2.3 million bearing interest at 3.95% per annum, which is repayable in equal monthly installments of approximately $0.3 million through the third quarter of 2014.
	Our outstanding borrowings under the credit facility at December 31, 2013 and 2012, respectively, were (in thousands):
		December 31,
		2013		2012
	Revolving credit facility	$	130,735	$	128,285
	Other debt	2,048		—
	Total debt	132,783		128,285
	Less: current portion	2,048		—
	Long-term debt	$	130,735	$	128,285
	At December 31, 2013 and 2012, respectively, letters of credit outstanding under the credit facility were $4.8 million and $2.6 million, respectively.
	In connection with our credit facility and amendments thereto, we have incurred $6.4 million in cumulative debt issuance costs through December 31, 2013, which are being amortized on a straight-line basis over the term of the credit facility.

Partners_Capital

Partners' Capital	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Partners' Capital	'
	Partners’ Capital
	Our capital accounts are comprised of approximately 2% general partner interest and 98% limited partner interests. Our limited partners have limited rights of ownership as provided for under our partnership agreement and the right to participate in our distributions. Our General Partner manages our operations and participates in our distributions, including certain incentive distributions pursuant to the new IDRs that are non-voting limited partner interests held by our General Partner.
	Series A Convertible Preferred Units
	On April 15, 2013, the Partnership, our General Partner and AIM Midstream Holdings entered into the ArcLight Transactions with HPIP, pursuant to which HPIP (i) acquired 90% of our General Partner and all of our subordinated units from AIM Midstream Holdings and (ii) contributed certain midstream assets and $15.0 million in cash to us in exchange for 5,142,857 Series A Units issued by the Partnership. Of the cash consideration paid by HPIP, approximately $2.5 million was used to pay certain transaction expenses of HPIP, and the remaining approximately $12.5 million was used to repay borrowings outstanding under the Partnership's credit facility in connection with the Fourth Amendment. As a result of these transactions, which were also consummated on April 15, 2013, HPIP acquired both control of our General Partner and a majority of our outstanding limited partnership interests. On April 15, 2013, our General Partner entered into the Third Amended & Restated Agreement of Limited Partnership (the “Amended Partnership Agreement”) of the Partnership providing for the creation and designation of the rights, preferences, terms and conditions of the Series A Units.
	The Series A Units receive distributions prior to distributions to Partnership common unitholders. Through October 1, 2014, the distributions to the Series A Unitholders are equal to $0.25 per unit and additional Series A Units in an amount equal to the cash portion of the distribution. Subsequent to that date, the distribution to each Series A Unit will be the greater of the distribution to be made on a per unit basis to common unitholders or approximately $0.4125 per unit. The Series A Units may be converted into common units on a one-to-one basis, subject to customary anti-dilutive adjustments, at the option of the unitholders on or any time after January 1, 2014.
	Upon any liquidation and winding up of the Partnership or the sale of substantially all of the assets of the Partnership, the holders of Series A Units generally will be entitled to receive, in preference to the holders of any of the Partnership's other securities, an amount equal to the sum of $17.50 multiplied by the number of Series A Units owned by such holders, plus all accrued but unpaid distributions on such Series A Units.
	Prior to the consummation of any recapitalization, reorganization, consolidation, merger, spin-off or other business combination in which the holders of common units are to receive securities, cash or other assets (a “Partnership Event”), we are obligated to make an irrevocable written offer, subject to consummation of the Partnership Event, to each holder of Series A Units to redeem all (but not less than all) of such holder's Series A Units for a price per Series A Unit payable in cash equal to the greater of:
	•	the sum of $17.50 and all accrued and accumulated but unpaid distributions for each Series A Unit; or
	•	an amount equal to the product of:
	(i) the number of common units into which each Series A Unit is convertible; and
	(ii) the sum of:
	(A) the cash consideration per common unit to be paid to the holders of common units pursuant to the Partnership Event, plus
	(B) the fair market value per common unit of the securities or other assets to be distributed to the holders of the common units pursuant to the Partnership Event.
	Upon receipt of such a redemption offer from us, each holder of Series A Units may elect to receive such cash amount or a preferred security issued by the person surviving or resulting from such Partnership Event and containing provisions substantially equivalent to the provisions set forth in the Amended Partnership Agreement with respect to the Series A Units without material abridgement.
	Except as provided in the Amended Partnership Agreement, the Series A Units have voting rights that are identical to the voting rights of the common units and will vote with the common units as a single class, with each Series A Unit entitled to one vote for each common unit into which such Series A Unit is convertible.
	The fair value of the Series A Units on April 15, 2013 was $17.50 per unit, or a total of $90.0 million and was issued by the Partnership in exchange for cash of approximately $12.5 million and net assets of $61.9 million contributed to the Partnership by our General Partner. The contribution of net assets of the High Point System was accounted for as a transaction between entities under common control whereby the High Point System was recorded at historical book value. As such, the value of the Series A Units in excess of the net assets contributed by our General Partner amounted to $15.6 million and was allocated pro-rata to our General Partner and existing limited partners' interest based on their ownership interests. The fair value measurement was based on significant inputs not observable in the market and thus represent a Level 3 measurement as defined by ASC 820. Primarily using the income approach, the fair value estimate was based on (i) present value of estimated future contracted distributions, (ii) an assumed discount rate of 18.0%, and (iii) an assumed distribution growth rate of 1.0% in 2014 and thereafter.
	The fair value of the additional Series A Units in an amount equal to the cash portion of the distribution was $25.17 per unit, or a total distribution of $4.8 million for the year ended December 31, 2013. Primarily using the market and income approach, the fair value estimate was based on (i) present value of estimated future contracted distributions, (ii) an option value of $7.27 per unit using a Black-Scholes model, (iii) an assumed discount rate of 10.0%, and (iv) an assumed distribution growth rate of 1.0% in 2014 and thereafter.
	Equity Restructuring
	Effective August 9, 2013, we executed an equity restructuring agreement ("Equity Restructuring") with our General Partner and HPIP. As part of the Equity Restructuring, the Partnership's 4,526,066 subordinated units and previous incentive distribution rights (the “former IDRs,” all of which were owned by our General Partner, which is controlled by HPIP) were combined into and restructured as a new class of incentive distribution rights (the “new IDRs”). Upon the issuance of the new IDRs, the subordinated units and former IDRs were cancelled. The new IDRs were allocated 85.02% to HPIP and 14.98% to our General Partner. The new IDRs entitle the holders of our incentive distribution rights to receive 48% of any quarterly cash distributions from available cash after the Partnership's common unitholders have received the full minimum quarterly distribution (0.4125 per unit) for each quarter plus any arrearages from prior quarters (of which there are currently none).
	Following the announcement of the Equity Restructuring Agreement, AIM Midstream Holdings filed an action in Delaware Chancery Court against HPIP and our General Partner seeking either rescission of the Equity Restructuring Agreement or, in the alternative, monetary damages. As a result of the action filed by AIM Midstream Holdings, the warrants that were issued by the Partnership, in conjunction with the Equity Restructuring, to our general partner for subsequent conveyance to AIM Midstream Holdings were cancelled effective August 29, 2013. In addition to the action filed by AIM Midstream Holdings, the escrowed funds of $12.5 million were not released to us. Accordingly, HPIP contributed $12.5 million in cash to us, which was used to satisfy obligations under our credit agreement and was accounted for as a contribution from our general partner.
	On February 5, 2014, we, HPIP and our general partner entered into a settlement (the “Settlement”) with AIM Midstream Holdings regarding the action filed in Delaware Chancery Court by AIM Midstream Holdings. Under the Settlement, among other things:
	·      HPIP and AIM Midstream Holdings amended the LLC Amendment to, among other things, amend the Sharing Percentages (as defined therein) such that HPIP’s sharing percentage thereafter is 95% and AIM Midstream Holdings’s Sharing Percentage is 5%;
	·      HPIP transferred all of the 85.02% of our outstanding new IDRs held by HPIP to our General Partner such that our General Partner owns 100% of the outstanding new IDRs; and
	·      we issued to AIM Midstream Holdings a warrant to purchase up to 300,000 common units of the Partnership at an exercise price of $0.01 per common unit (the “Warrant”), which Warrant, among other terms, (i) is exercisable at any time on or after February 8, 2014 until the tenth anniversary of February 5, 2014, (ii) contains cashless exercise provisions and (iii) contains customary anti-dilution and other protections. The Warrant was exercised on February 21, 2014.
	Equity Offering
	On December 11, 2013, the Partnership and certain of its affiliates entered into an underwriting agreement (the “Underwriting Agreement”) with Barclays Capital Inc. (the “Underwriter”), providing for the issuance and sale by the Partnership, and the purchase by the Underwriter, of 2,568,712 common units representing limited partner interests in the Partnership at a price to the public of $22.47 per common unit. The Partnership used the net proceeds of $54.9 million to fund a portion of the purchase price for Blackwater.
	Outstanding Units
	The numbers of units outstanding as of December 31, 2013, 2012 and 2011, respectively, were as follows (in thousands):
		December 31,
		2013	2012	2011
	Series A convertible preferred units	5,279	—	—
	Limited partner common units	7,414	4,639	4,561
	Limited partner subordinated units	—	4,526	4,526
	General partner units	185	185	185

Earnings_per_Unit_Notes

Earnings per Unit (Notes)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'
Net Income Loss Per Limited and General Partner Unit [Text Block]	'
	Net Income (Loss) per Limited and General Partner Unit
	Net income (loss) is allocated to the general partner and the limited partners in accordance with their respective ownership percentages, after giving effect to distributions on Series A preferred convertible units and incentive distributions paid to the general partner. Basic and diluted net income (loss) per limited partner unit is calculated by dividing limited partners’ interest in net income (loss) by the weighted average number of outstanding limited partner units during the period.
	Unvested unit-based payment awards that contain non-forfeitable rights to distributions (whether paid or unpaid) are classified as participating securities and are included in our computation of basic and diluted net income per limited partner unit.
	We compute earnings per unit using the two-class method. The two-class method requires that securities that meet the definition of a participating security be considered for inclusion in the computation of basic earnings per unit. Under the two-class method, earnings per unit is calculated as if all of the earnings for the period were distributed under the terms of the partnership agreement, regardless of whether the general partner has discretion over the amount of distributions to be made in any particular period, whether those earnings would actually be distributed during a particular period from an economic or practical perspective, or whether the general partner has other legal or contractual limitations on its ability to pay distributions that would prevent it from distributing all of the earnings for a particular period.
	The two-class method does not impact our overall net income or other financial results; however, in periods in which aggregate net income exceeds our aggregate distributions for such period, it will have the impact of reducing net income per limited partner unit. This result occurs as a larger portion of our aggregate earnings, as if distributed, is allocated to the incentive distribution rights of the general partner, even though we make distributions on the basis of available cash and not earnings. In periods in which our aggregate net income does not exceed our aggregate distributions for such period, the two-class method does not have any impact on our calculation of earnings per limited partner unit. We have no dilutive securities, therefore basic and diluted net income per unit are the same.
	We determined basic and diluted net income (loss) per general partner unit and limited partner unit as follows, (in thousands, except per unit amounts):
		Year Ended December 31,
		2013			2012			2011
	Net loss from continuing operations	$	(31,151	)	$	(6,571	)	$	(12,030	)
	Net income attributable to noncontrolling interests	633			256			—
	Net loss from continuing operations attributable to the Partnership	(31,784		)	(6,827		)	(12,030		)
	Less:
	Distributions on Series A Preferred Units	24,117			—			—
	General partner's distributions	464			322			864
	General partner's share in undistributed loss	(1,708		)	(458		)	(1,112		)
	Blackwater net loss from continuing operations	(716		)	—			—
	Net loss from continuing operations available to limited partners	(53,941		)	(6,691		)	(11,782		)
	Net (loss) income from discontinued operations available to limited partners	(1,893		)	313			325
	Net loss available to limited partners	$	(55,834	)	$	(6,378	)	$	(11,457	)
	Weighted average number of units used in computation of limited partners’ net loss per unit (basic and diluted)	7,981			9,113			6,997
	Limited partners’ net loss from continuing operations per unit (basic and diluted)	$	(6.76	)	$	(0.73	)	$	(1.68	)
	Limited partners’ net loss (income) from discontinued operations per unit (basic and diluted)	(0.24		)	0.03			0.04
	Limited partners’ net loss per unit (basic and diluted)	$	(7.00	)	$	(0.70	)	$	(1.64	)

LongTerm_Incentive_Plan

Long-Term Incentive Plan	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Long-Term Incentive Plan	'
	Long-Term Incentive Plan
	Our general partner manages our operations and activities and employs the personnel who provide support to our operations. On November 2, 2009, the board of directors of our general partner adopted an LTIP for its employees, consultants and directors who perform services for it or its affiliates. On May 25, 2010, the board of directors of our general partner adopted an amended and restated LTIP. On July 11, 2012, the board of directors of our general partner adopted a second amended and restated long-term incentive plan that effectively increased available awards by 871,750 units. At December 31, 2013, 2012 and 2011, there were 855,089, 920,193 and 54,827 units, respectively, available for future grant under the LTIP.
	Ownership in the awards is subject to forfeiture until the vesting date. The LTIP is administered by the board of directors of our general partner. The board of directors of our general partner, at its discretion, may elect to settle such vested phantom units with a number of units equivalent to the fair market value at the date of vesting in lieu of cash. Although our general partner has the option to settle in cash upon the vesting of phantom units, our general partner has not historically settled these awards in cash. Although other types of awards are contemplated under the LTIP, the only currently outstanding awards are phantom units without dividend equivalent rights ("DERs").
	Generally, grants issued under the LTIP vest in increments of 25% on each grant anniversary date and do not contain any vesting requirements other than continued employment.
	Prior to our initial public offering, the fair value of the grants issued was calculated by the general partner based on several valuation models, including: a discounted cash flow ("DCF") model, a comparable company multiple analysis and a comparable recent transaction multiple analysis. As it relates to the DCF model, the model includes certain market assumptions related to future throughput volumes, projected fees and/or prices, expected costs of sales and direct operating costs and risk adjusted discount rates. Both the comparable company analysis and recent transaction analysis contain significant assumptions consistent with the DCF model, in addition to assumptions related to comparability, appropriateness of multiples (primarily based on EBITDA and DCF) and certain assumptions in the calculation of enterprise value.
	The following table summarizes our unit-based awards for each of the periods indicated, in units:
		Year Ended December 31,
		2013		2012		2011
	Outstanding at beginning of period	90,938		162,860		205,864
	Granted	114,336		38,595		19,414
	Forfeited	(18,320	)	(12,517	)	—
	Vested	(111,425	)	(98,000	)	(62,418	)
	Outstanding at end of period	75,529		90,938		162,860
	Fair value per unit	$13.36 to $25.60		$14.70 to $21.40		$14.70 to $19.69
	The fair value of our phantom units, which are subject to equity classification, is based on the fair value of our units at the grant date. Compensation costs related to these awards including amortization, modification costs, DER payments and the cost of the DER buyout for the years ended December 31, 2011, was $3.4 million, which is classified as equity compensation expense in the consolidated statement of operations and the non-cash portion in partners’ capital on the consolidated balance sheet. There were no remaining DERs as of or for the year ended December 31, 2013.
	In June 2011, certain existing LTIP grant agreements were modified to exclude the DER provision in exchange for a cash payment of $1.5 million, which has been included in equity compensation expense in the consolidated statement of operations.
	The total fair value of vesting units at the time of vesting was $2.2 million, $1.9 million, and $1.2 million for the years ended December 31, 2013, 2012, and 2011, respectively.
	The total compensation cost related to unvested awards not yet recognized at December 31, 2013, 2012, and 2011 was $0.9 million, $1.4 million, and $2.7 million, respectively, and the weighted average period over which this cost is expected to be recognized as of December 31, 2013, is approximately 1.9 years.

PostEmployment_Benefits

Post-Employment Benefits	12 Months Ended
	Dec. 31, 2013
Compensation and Retirement Disclosure [Abstract]	'
Post-Employment Benefits	'
	Post-Employment Benefits
	We sponsor a contributory postretirement plan that provides medical, dental and life insurance benefits for qualifying U.S. retired employees (referred to as the “OPEB Plan”).
	The tables below detail the changes in the benefit obligation, the fair value of the plan assets and the recorded asset or liability of the OPEB Plan using the accrual method (in thousands):
			Year Ended December 31,
			2013				2012				2011
	Change in benefit obligation
	Benefit obligation, beginning of period		$	472			$	466			$	869
	Service cost		5				4				3
	Interest cost		15				18				22
	Actuarial (gain) loss		(29		)		22				(367		)
	Plan amendments		126				—				—
	Benefits paid		(57		)		(38		)		(61		)
	Benefit obligation, end of period		$	532			$	472			$	466
	Change in plan assets
	Fair value of plan assets, beginning of period		$	1,552			$	1,432			$	1,319
	Actual return on plan assets		(53		)		84				99
	Employer’s contributions		90				90				90
	Benefits paid		(61		)		(54		)		(76		)
	Fair value of plan assets, end of period		$	1,528			$	1,552			$	1,432
	Funded status
	Funded status		$	996			$	1,080			$	966
	The amounts of plan assets recognized in our consolidated balance sheets were as follows (in thousands):
			December 31,
			2013				2012				2011
	Other assets		$	996			$	1,080			$	966
	The amounts included in accumulated other comprehensive income at December 31, 2013, 2012 and 2011 that have not been recognized as components of net periodic benefit expenses are $(0.1) million, $(0.1) million and $0.4 million, respectively, which relate to net gains (losses).
	Components of Net Periodic (Benefit) Cost and Other amounts Recognized in Other Comprehensive Income (in thousands):
			Year Ended December 31,
			2013				2012				2011
	Net Periodic (Benefit) Cost
	Service cost		$	5			$	4			$	3
	Interest cost		15				18				22
	Expected return on plan assets		(70		)		(67		)		(60		)
	Amortization of net (gain) loss		(23		)		(43		)		(47		)
	Net periodic (benefit) cost		$	(73	)		$	(88	)		$	(82	)
	Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income
	Net loss (gain)		$	247			$	64			$	(359	)
	Total recognized in other comprehensive income		247				64				(359		)
	Total recognized in net periodic benefit cost and other comprehensive income		$	174			$	(24	)		$	(441	)
	The estimated net gain that will be amortized from accumulated other comprehensive income into net periodic benefit cost over the next fiscal year is less than $0.1 million.
	Economic assumptions
	The assumptions made in measurement of the projected benefit obligations or assets of the OPEB Plan were as follows:
			Year Ended December 31,
			2013			2012			2011
	Discount rate		4.57	%		3.42	%		3.96	%
	Expected return on plan assets		4.5	%		4.5	%		4.5	%
	Health care trend rate		4.5	%		3	%		3	%
	A one percent increase in the assumed medical and dental care trend rate would result in an increase of less than $0.1 million in the accumulated post-employment benefit obligations. A one percent decrease in the assumed medical and dental care trend rate would result in a decrease of less than $0.1 million in the accumulated post-employment benefit obligations.
	The above table reflects the expected long-term rates of return on assets of the OPEB Plan on a weighted-average basis. The overall expected rates of return are based on the asset allocation targets with estimates for returns on equity and debt securities based on long-term expectations. We believe this rate approximates the return we will achieve over the long-term on the assets of our plans. Historically, we have used a discount rate that corresponds to one or more high quality corporate bond indices as an estimate of our expected long-term rate of return on plan assets for our OPEB Plan assets. For 2013, 2012 and 2011 we selected the discount rate using the Citigroup Pension Discount Curve, or CPDC. The CPDC spot rates represent the equivalent yield on high-quality, zero-coupon bonds for specific maturities. These rates are used to develop a single, equivalent discount rate based on the OPEB Plan’s expected future cash flows.
	Expected future benefit payments
	The following table presents the benefits expected to be paid in each of the next five fiscal years, and in the aggregate for the five years thereafter by the OPEB Plan (in thousands):
	For the year ending
	2014	$	28
	2015	29
	2016	28
	2017	27
	2018	27
	Five years thereafter	157
	The expected future benefit payments are based upon the same assumptions used to measure the projected benefit obligations of the OPEB Plan including benefits associated with future employee service.
	Future contributions to the Plans
	We expect to make contributions of $0.1 million to the OPEB Plan for the year ending December 31, 2014.
	Plan assets
	The weighted average asset allocation of our OPEB Plan at the measurement date by asset category, which are all classified as Level 1 investments, are as follows:
		December 31,
		2013			2012			2011
Fixed income (a)		70.1	%		72.2	%		72.1	%
Cash and short term assets (b)		29.9	%		27.8	%		27.9	%
Total		100	%		100	%		100	%
(a)	United States government securities, municipal corporate bonds and notes and asset backed securities
(b)	Cash and securities with maturities of one year or less

Income_Tax_Notes

Income Tax (Notes)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Tax Disclosure [Text Block]	'
	Income Taxes
	The Partnership is not a taxable entity for U.S. federal income tax purposes or for the majority of states that impose an income tax. Taxes on our net income generally are borne by our unitholders through the allocation of taxable income. However, Blackwater is a taxable entity. The Partnership follows the provisions of ASC 740 “Accounting For Income Taxes,” which provides for recognition of deferred tax assets and liabilities for deductible temporary timing differences, operating loss carryforwards, statutory depletion carryforwards and tax credit carryforwards net of a valuation allowance for any asset for which it is more likely than not will not be realized in the Partnership’s tax return. An analysis of the Partnership’s deferred taxes is as follows (in thousands):
		31-Dec-13
	Deferred tax assets:
	Net operating loss carryforwards	$	5,455
	Other	182
	Total deferred tax assets	5,637
	Deferred tax liabilities:
	Property, plant and equipment	9,022
	Intangible assets	1,364
	Total deferred tax liabilities	10,386
	Deferred income tax liability, net	$	(4,749	)
	At December 31, 2013, we had approximately $14.0 million of operating loss carryforwards. The net operating loss carryforwards would begin to expire in 2028. Some of our net operating losses may be limited by section 382 of the Internal Revenue Code due to the change in control that occurred in December 2013 and another change in control that occurred in October 2012.
	Management assessed its various income tax positions and this assessment resulted in no adjustment to the tax asset or liability. The preparation of our various tax returns requires the use of estimates for federal and state income tax purposes. These estimates may be subjected to review by the respective taxing authorities. A revision, if any, to an estimate may result in an assessment of additional taxes, penalties and interest. At this time, a range in which our estimates may change is not quantifiable and a change, if any, is not expected to be material. We will account for interest and penalties relating to uncertain tax provisions in the current period statement of operations, as necessary. We have not recorded any adjustment to our financial statements as a result of this interpretation. We have tax years 2009 through 2012 remaining subject to examination by various federal and state tax jurisdictions, as applicable.
	The provision for taxes is only attributable to the activities of certain affiliates of Blackwater. The details of the provision for taxes on income for the year ended December 31, 2013, are as follows (in thousands):
		Year Ended December 31, 2013
	Net loss before income tax benefit	(31,646		)
	Federal statutory rate	34		%
	Federal income tax benefit at statutory rate	10,760
	Reconciling items:
	Partnership loss not subject to income tax	(10,350		)
	Income not subject to corporate-level tax	222
	State and local tax benefit	71
	Return to provision true-ups	(175		)
	Other	(33		)
	Income tax benefit	$	495
	The income tax provision related to continuing operations consist of the following (in thousands):
		Year Ended December 31, 2013
	Current income tax	$	—
	Deferred income tax benefit	495
	Effective income tax rate	1.6		%
	The effective tax rate for the year ended December 31, 2013, was less than the statutory rate primarily due to the inclusion of income (loss) of the Partnership, which is not taxed at the subsidiary level that is subject to corporate income tax.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	Environmental matters
	We are subject to federal and state laws and regulations relating to the protection of the environment. Environmental risk is inherent to natural gas pipeline, NGL and crude pipelines and operations, as well as terminal operations and we could, at times, be subject to environmental cleanup and enforcement actions. We attempt to manage this environmental risk through appropriate environmental policies and practices to minimize any impact our operations may have on the environment.
	Commitments and contractual obligations
	Future non-cancelable commitments related to certain contractual obligations as of December 31, 2013, are presented below (in thousands):
		Payments Due by Period
		Total			2014			2015			2016		2017		2018		Thereafter
	Operating leases and service contracts	$	6,149		$	959		$	1,012		$	814	$	810	$	584	$	1,970
	ARO	34,636			—			—			7,867		—		—		26,769
	Total	$	40,785		$	959		$	1,012		$	8,681	$	810	$	584	$	28,739
	For the periods indicated, total expenses related to operating leases, asset retirement obligations, land site leases and right-of-way agreements were (in thousands):
			Year Ended December 31,
			2013			2012			2011
	Operating leases		$	1,051		$	941		$	803
	ARO		554			32			1,393
			$	1,605		$	973		$	2,196
	Gloria System Matter
	We have been named in a lawsuit in the District Court of Jefferson Parish, Louisiana related to right of way maintenance and damages on our Louisiana Intrastate (Gloria) pipeline system related to a servitude agreement entered into by a predecessor in 1956. The landowner has sued us claiming that we have failed to maintain the pipeline right-of-way, allegedly causing erosion of the pipeline canal, erosion of levees, and deterioration of the adjacent marshland. The landowner seeks damages for the cost to narrow the pipeline canal, rebuild the pipeline levees, and restore the damaged marsh.
	While we cannot predict the ultimate outcome of this litigation, we disagree with the damage claims asserted in the lawsuit and we are vigorously defending ourselves.
	Bazor Ridge Emissions Matter
	In July 2011, in the course of preparing our annual filing for 2010 with the Mississippi Department of Environmental Quality (“MDEQ”) as required by our Title V Air Permit, we determined that we underreported to the MDEQ the SO2 (sulfur dioxide) emissions from the Bazor Ridge plant for 2009 and 2010. In addition, we determined that certain SO2 emissions during 2009 and 2010 exceeded the reportable quantity threshold under the federal Emergency Planning and Community Right-to-Know Act, or EPCRA, requiring notification of various governmental authorities. We did not make any such EPCRA notifications.
	In July 2011, we self-reported these issues to the MDEQ and EPA Region IV. In January 2012, we met with EPA Region IV representatives, and have agreed to a settlement with respect to the EPCRA reporting issue. A Consent Agreement and Final Order was executed, which included a civil penalty of $23,010. After discussion with the MDEQ, in February 2012 we submitted an application to amend our Title V Air Permit to account for these SO2 emissions. The MDEQ is currently processing this permit application. In December 2011, EPA Region IV performed an inspection of the plant, and they followed up with an Information Request in May 2012. We have responded to this Information Request and do not anticipate any further action required by the Partnership at this time.

RelatedParty_Transactions

Related-Party Transactions	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related-Party Transactions	'
	Related-Party Transactions
	Employees of our general partner are assigned to work for us. Where directly attributable, the costs of all compensation, benefits expenses and employer expenses for these employees are charged directly by our general partner to American Midstream, LLC, which, in turn, charges the appropriate subsidiary. Our general partner does not record any profit or margin for the administrative and operational services charged to us. During the years ended December 31, 2013, 2012, and 2011 administrative and operational services expenses of $14.2 million, $12.5 million and $9.6 million, respectively, were charged to us by our general partner. For the year ended December 31, 2013, 2012 and 2011, our general partner incurred approximately $1.8 million, $0.4 million and zero of costs associated with certain business development activities, respectively. If the business development activities result in a project that will be pursued and funded by the Partnership, we will reimburse our general partner for the business development costs related to that project.
	The High Point System, along with $15.0 million in cash, was contributed to us by HPIP in exchange for 5,142,857 Series A Units. Of the cash consideration paid by HPIP, approximately $2.5 million was used to pay certain transaction expenses of HPIP, and the remaining approximately $12.5 million was used to repay borrowings outstanding under the Partnership's credit facility in connection with the Fourth Amendment.
	In connection with the Blackwater Acquisition, our General Partner contributed the net assets of Blackwater which were recorded at their historical book value of $22.7 million for consideration of $63.9 million, of which $27.7 million was accounted for as a cash distribution to the general partner. The consideration also included 125,500 limited partner units which were accounted for as a non-cash distribution to the general partner at a fair value of $3.1 million. See read Note 2. "Acquisitions" for more information.
	On October 9, 2012, Blackwater entered into a Convertible Promissory Note (the “BWHD Note”) with ArcLight Energy Partners Fund V, L.P. (“AL Fund V”), in the amount of $20.0 million. AL Fund V is a related party to the Partnership. The BWHD Note was paid off during the fourth quarter of 2013 as part of the Blackwater Acquisition.
	Prior to our IPO, we had entered into an advisory services agreement with the former 100% interest owner of General Partner, American Infrastructure MLP Management, L.L.C., American Infrastructure MLP PE Management, L.L.C., and American Infrastructure MLP Associates Management, L.L.C., as the advisors. The agreement provided for the payment of $0.3 million in 2010 and annual fees of $0.3 million plus annual increases in proportion to the increase in budgeted gross revenues thereafter. In exchange, the advisors agreed to provide us services in obtaining equity, debt, lease and acquisition financing, as well as providing other financial, advisory and consulting services. Under this agreement, $0.2 million had been recorded to selling, general and administrative expenses for the year ended December 31, 2011.
	On August 1, 2011, and in connection with our IPO, we terminated the advisory services agreement in exchange for a payment of $2.5 million.

Reporting_Segments

Reporting Segments	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Reporting Segments	'
	Reporting Segments
	Our operations are located in the United States and are organized into three reporting segments: (i) Gathering and Processing, (ii) Transmission, and (iii) Terminals.
	Gathering and Processing
	Our Gathering and Processing segment provides “wellhead-to-market” services to producers of natural gas and oil, which include transporting raw natural gas from the wellhead through gathering systems, treating the raw natural gas, processing raw natural gas to separate the NGLs and selling or delivering pipeline quality natural gas and NGLs to various markets and pipeline systems.
	Transmission
	Our Transmission segment transports and delivers natural gas from producing wells, receipt points or pipeline interconnects for shippers and other customers, including local distribution companies, or LDCs, utilities and industrial, commercial and power generation customers.
	Terminals
	Our Terminals segment provides above-ground storage services at our marine terminals that support various commercial customers, including commodity brokers, refiners and chemical manufacturers to store a range of products, including crude oil, bunker fuel, distillates, chemicals and agricultural products.
	These segments are monitored separately by management for performance and are consistent with internal financial reporting. These segments have been identified based on the differing products and services, regulatory environment and the expertise required for these operations. Gross margin is a performance measure utilized by management to monitor the business of each segment.
	The following tables set forth our segment information for the periods indicated (in thousands):
		Year Ended December 31, 2013
		Gathering				Transmission				Terminals (a)			Total
		and
		Processing
	Total revenue	$	192,446			$	90,377			$	9,831		$	292,654
	Less:
	COMA Income	689				154				—			843
	Unrealized loss on commodity derivatives	(1,041		)		—				—			(1,041		)
	Purchases of natural gas, NGL's and condensate	156,334				57,815				—			214,149
	Direct operating expenses	—				—				2,080			2,080
	Segment gross margin (a)	36,464				32,408				7,751			76,623
	Direct operating expenses	(14,214		)		(13,259		)		—			(27,473		)
	COMA Income												843
	Unrealized loss on commodity derivatives												(1,041		)
	Selling, general and administrative expenses												(21,402		)
	Equity compensation expense												(2,094		)
	Depreciation, amortization and accretion expense												(29,999		)
	Gain on involuntary conversion of property, plant and equipment												343
	Loss on impairment of property, plant and equipment												(18,155		)
	Interest expense												(9,291		)
	Income tax benefit												495
	Loss from operations of disposal groups, net of tax												(2,255		)
	Net loss												(33,406		)
	Less: Net income attributable to non-controlling interests												633
	Net loss attributable to the Partnership												$	(34,039	)
	(a)	Terminals segment amounts are for the period from April 15, 2013 to December 31, 2013.
		Year Ended December 31, 2012
		Gathering				Transmission				Total
		and
		Processing
	Total revenue	$	145,714			$	52,529			$	198,243
	Less:
	COMA Income	673				2,700				3,373
	Unrealized gain on commodity derivatives	992				—				992
	Purchases of natural gas, NGL's and condensate	108,656				36,516				145,172
	Segment gross margin (a)	35,393				13,313				48,706
	Direct operating expenses	(11,767		)		(5,031		)		(16,798		)
	COMA Income									3,373
	Unrealized gain on commodity derivatives									992
	Selling, general and administrative expenses									(14,309		)
	Equity compensation expense									(1,783		)
	Depreciation, amortization and accretion expense									(21,284		)
	Loss on involuntary conversion of property, plant and equipment									(1,021		)
	Gain on sale of assets, net									123
	Interest expense									(4,570		)
	Income from operations of disposal groups									319
	Net loss									(6,252		)
	Less: Net income attributable to non-controlling interests									256
	Net loss attributable to the Partnership									$	(6,508	)
		Year Ended December 31, 2011
		Gathering				Transmission				Total
		and
		Processing
Total revenue	$	160,953			$	66,766			$	227,719
Less:
Realized loss on early termination of commodity derivatives	(2,998		)		—				(2,998		)
Unrealized loss on commodity derivatives	(541		)		—				(541		)
Purchases of natural gas, NGL's and condensate	134,369				53,029				187,398
Segment gross margin (a)	30,123				13,737				43,860
Direct operating expenses	(6,199		)		(5,220		)		(11,419		)
Realized loss on early termination of commodity derivatives									(2,998		)
Unrealized loss on commodity derivatives									(541		)
Selling, general and administrative expenses									(11,082		)
Advisory services agreement termination fee									(2,500		)
Transaction expenses									—
Equity compensation expense									(3,357		)
Depreciation, amortization and accretion expense									(20,449		)
Gain on acquisition of assets									565
Loss on sale of assets, net									399
Interest expense									(4,508		)
Income from operations of disposal groups									332
Net loss attributable to the Partnership									$	(11,698	)
(a)	Segment gross margin for our Gathering and Processing segment consists of revenue less purchases of natural gas, NGLs and condensate and COMA. Segment gross margin for our Transmission segment consists of revenue, less purchases of natural gas and COMA. Segment gross margin for our Terminals segment consists of revenue, less direct operating expenses. Gross margin consists of the sum of the segment gross margin amounts for each of these segments. As an indicator of our operating performance, gross margin should not be considered an alternative to, or more meaningful than, net income or cash flow from operations as determined in accordance with GAAP. Our gross margin may not be comparable to a similarly titled measure of another company because other entities may not calculate gross margin in the same manner. Effective October 1, 2012, we changed our segment gross margin measure to exclude construction, operating and maintenance agreement (“COMA”) income. Effective January 1, 2011, we changed our segment gross margin measure to exclude unrealized non-cash mark-to-market adjustments related to our commodity derivatives. Effective April 1, 2011, we changed our segment gross margin measure to exclude realized early termination costs on commodity derivatives.
For a definition of gross margin and a reconciliation to its most directly comparable financial measure calculated and presented in accordance with GAAP and a discussion of how we use gross margin to evaluate our operating performance, please read Item 7. "Management's Discussion and Analysis, How We Evaluate Our Operations”.
Asset information, including capital expenditures, by segment is not included in reports used by our management to monitor our performance and therefore is not disclosed.
The following table summarizes the percentage of revenue earned from those customers in each segment that exceed 10% or greater of the Partnership's consolidated segment revenue for the each of the periods presented below:
	Year Ended December 31,
	2013			2012			2011
Gathering and Processing:
Customer A	43	%		40	%		55	%
Customer B	19	%		11	%		—
Customer D	—			12	%		16	%
Other	38	%		37	%		29	%
Total	100	%		100	%		100	%
Transmission:
Customer C	39	%		50	%		57	%
Customer D	16	%		22	%		22	%
Customer E	—			10	%		—
Other	45	%		18	%		21	%
Total	100	%		100	%		100	%
Terminals:
Customer F	20	%		—			—
Customer B	17	%		—			—
Customer G	16	%		—			—
Customer H	13	%		—			—
Other	34	%		—			—
Total	100	%		—			—

Quarterly_Financial_Data_Notes

Quarterly Financial Data (Notes)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Quarterly Financial Information [Text Block]	'
	Quarterly Financial Data (Unaudited)
	Summarized unaudited quarterly financial data for 2013 and 2012 are as follows (in thousands, except per unit amounts):
		First			Second			Third			Fourth
		Quarter (a)			Quarter			Quarter			Quarter
	Year Ended December 31, 2013
	Total revenues	$	59,402		$	77,608		$	79,536		$	76,108
	Gross margin (b)	12,476			19,158			21,380			23,609
	Operating (loss) income	(1,740		)	(17,780		)	(210		)	(2,625		)
	Net loss from continuing operations	(3,471		)	(19,996		)	(2,632		)	(5,052		)
	Income (loss) from operations of disposal groups	73			(1,930		)	91			(489		)
	Net income attributable to noncontrolling interest	155			188			190			100
	Net loss attributable to the Partnership	(3,553		)	(22,114		)	(2,731		)	(5,641		)
	General partner’s interest in net loss	(70		)	(905		)	(221		)	(209		)
	Limited partners’ interest in net loss	$	(3,483	)	$	(21,209	)	$	(2,510	)	$	(5,432	)
	Limited partners’ (loss) income per unit:
	Loss from continuing operations	$	(0.39	)	$	(4.00	)	$	(0.82	)	$	(1.55	)
	Income (loss) from discontinued operations	0.01			(0.20		)	0.02			(0.07		)
	Net loss	$	(0.38	)	$	(4.20	)	$	(0.80	)	$	(1.62	)
	Year Ended December 31, 2012
	Total revenues	$	44,857		$	43,322		$	53,401		$	56,663
	Gross margin (b)	12,560			11,253			12,979			11,914
	Operating income (loss)	2,417			3,077			(2,513		)	(4,982		)
	Net income (loss) from continuing operations	1,660			2,252			(4,014		)	(6,469		)
	Income (loss) from operations of disposal groups	31			75			(12		)	225
	Net income (loss) attributable to noncontrolling interest	—			—			249			7
	Net income (loss) attributable to the Partnership	1,691			2,327			(4,275		)	(6,251		)
	General partner’s interest in net income (loss)	34			46			(85		)	(124		)
	Limited partners’ interest in net income (loss)	$	1,657		$	2,281		$	(4,190	)	$	(6,127	)
	Limited partners’ income (loss) per unit:
	Income (loss) from continuing operations	$	0.18		$	0.24		$	(0.46	)	$	(0.69	)
	Income (loss) from discontinued operations	—			0.01			—			0.02
	Net income (loss)	$	0.18		$	0.25		$	(0.46	)	$	(0.67	)
	(a)	During the fourth quarter of 2012, we identified revenues in the amount of $0.3 million associated with proceeds received in connection with COMA reimbursable projects that were incorrectly recognized in the first quarter of 2012 that should have been recognized ratably during each of the succeeding quarters of 2012 for approximately $0.1 million per quarter. In addition, we recorded in the first quarter of 2012 and for the year ended December 31, 2012, out-of-period adjustments amounting to $0.1 million for the correction of immaterial errors associated with additional depreciation expense and selling, general and administrative expense. Based upon our evaluation of relevant factors, we concluded that these errors were not material to any previously issued and current consolidated financial statements.
	(b)	For a definition of gross margin and a reconciliation to its most directly comparable financial measure calculated and presented in accordance with GAAP and a discussion of how we use gross margin to evaluate our operating performance, please read Item 7. "Management's Discussion and Analysis, How We Evaluate Our Operations”.

Subsidiary_Guarantors

Subsidiary Guarantors	12 Months Ended
	Dec. 31, 2013
Subsidiary Guarantors [Abstract]	'
Subsidiary Guarantors	'
	Subsidiary Guarantors
	The Partnership filed a registration statement on Form S-3 with the SEC to register, among other securities, debt securities, which was effective in the fourth quarter of 2012. The subsidiaries of the Partnership (the "Subsidiaries") are co-registrants with the Partnership, and the registration statement registers guarantees of debt securities by one or more of the Subsidiaries (other than American Midstream Finance Corporation, a 100% owned subsidiary of the Partnership whose sole purpose is to act as co-issuer of such debt securities). The financial position and operations of the co-issuer are minor and therefore have been included with the Parent's financial information. As of June 30, 2012, the Subsidiaries were 100% owned by the Partnership and any guarantees by the Subsidiaries will be full and unconditional. As of December 31, 2013, the Subsidiaries have an investment in the non-guarantor subsidiaries equal to a 92.2% undivided interest in its Chatom system. The Partnership has no assets or operations independent of the Subsidiaries, and there are no significant restrictions upon the ability of the Subsidiaries to distribute funds to the Partnership. In the event that more than one of the Subsidiaries provide guarantees of any debt securities issued by the Partnership, such guarantees will constitute joint and several obligations. None of the assets of the Partnership or the Subsidiaries represent restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act of 1933, as amended. For purposes of the following condensed consolidating financial information, the Partnership's investments in its Subsidiaries and the guarantor subsidiaries' investment in its 92.2% undivided interest in the Chatom system are presented in accordance with the equity method of accounting. The financial information may not necessarily be indicative of the financial position, results of operations, or cash flows had the subsidiary guarantors operated as independent entities. Condensed consolidating financial information for the Partnership, its combined guarantor subsidiaries and non-guarantor subsidiary as of December 31, 2013 and 2012, and for those years ended is as follows (in thousands):
		Consolidating Balance Sheet
		31-Dec-13
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Consolidating Adjustments			Consolidated
	Assets
	Current assets
	Cash and cash equivalents	$	1		$	392		$	—		$	—		$	393
	Accounts receivable	—			4,461			2,361			—			6,822
	Unbilled revenue	—			17,325			4,680			—			22,005
	Risk management assets	—			473			—			—			473
	Other current assets	84			6,942			555			(84		)	7,497
	Current assets held for sale	—			1,268			—			—			1,268
	Total current assets	85			30,861			7,596			(84		)	38,458
	Property, plant and equipment, net	—			254,465			58,045			—			312,510
	Note receivable	27,315			—			—			(27,315		)	—
	Goodwill	—			16,447			—			—			16,447
	Intangible assets, net	—			3,682			—			—			3,682
	Other assets, net	—			8,321			743			—			9,064
	Noncurrent assets held for sale, net	—			1,914			—			—			1,914
	Investment in subsidiaries	142,758			57,750			—			(200,508		)	—
	Total assets	$	170,158		$	373,440		$	66,384		$	(227,907	)	$	382,075
	Liabilities and Partners’ Capital
	Current liabilities
	Accounts payable	$	30		$	2,902		$	329		$	—		$	3,261
	Accrued gas purchases	—			13,290			3,104			—			16,394
	Accrued expenses and other current liabilities	1,478			13,563			101			(84		)	15,058
	Current portion of long-term debt	—			2,048			—			—			2,048
	Risk management liabilities	—			423			—			—			423
	Current liabilities held for sale	—			1,106			—			—			1,106
	Total current liabilities	1,508			33,332			3,534			(84		)	38,290
	Risk management liabilities - long term	—			101			—			—			101
	Asset retirement obligation	—			34,164			472			—			34,636
	Other liabilities	—			191			—			—			191
	Long-term debt	—			158,050			—			(27,315		)	130,735
	Deferred tax liability	—			4,749			—			—			4,749
	Noncurrent liabilities held for sale	—			95			—			—			95
	Total liabilities	1,508			230,682			4,006			(27,399		)	208,797
	Convertible preferred units
	Series A convertible preferred units	94,811			—			—			—			94,811
	Total partners' capital	73,839			142,758			57,750			(200,508		)	73,839
	Noncontrolling interest	—			—			4,628			—			4,628
	Total equity	73,839			142,758			62,378			(200,508		)	78,467
	Total liabilities and partners' capital	$	170,158		$	373,440		$	66,384		$	(227,907	)	$	382,075
		Consolidating Balance Sheet
		31-Dec-12
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Consolidating Adjustments			Consolidated
	Assets
	Current assets
	Cash and cash equivalents	$	1		$	575		$	—		$	—		$	576
	Accounts receivable	—			1,612			346			—			1,958
	Unbilled revenue	—			18,102			3,410			—			21,512
	Risk management assets	—			969			—			—			969
	Other current assets	—			2,967			259			—			3,226
	Total current assets	1			24,225			4,015			—			28,241
	Property, plant and equipment, net	—			165,001			58,818			—			223,819
	Investment in subsidiaries	80,164			51,613			—			(131,777		)	—
	Other assets, net	—			4,636			—			—			4,636
	Total assets	$	80,165		$	245,475		$	62,833		$	(131,777	)	$	256,696
	Liabilities and Partners’ Capital
	Current liabilities
	Accounts payable	$	—		$	5,100		$	427		$	—		$	5,527
	Accrued gas purchases	—			14,606			2,428			—			17,034
Accrued expenses and other current liabilities	—			9,150			469			—			9,619
Total current liabilities	—			28,856			3,324			—			32,180
Asset retirement obligations	—			7,861			458			—			8,319
Other liabilities	—			309			—			—			309
Long-term debt	—			128,285			—			—			128,285
Total liabilities	—			165,311			3,782			—			169,093
Partners' capital
Total partners' capital	80,165			80,164			51,613			(131,777		)	80,165
Noncontrolling interest	—			—			7,438			—			7,438
Total equity	80,165			80,164			59,051			(131,777		)	87,603
Total liabilities and partners' capital	$	80,165		$	245,475		$	62,833		$	(131,777	)	$	256,696
	Consolidating Statements of Operations
	Year ended December 31, 2013
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Consolidating Adjustments			Consolidated
Revenue	$	—		$	242,395		$	56,080		$	(5,849	)	$	292,626
Unrealized gain on commodity derivatives	—			(369		)	397			—			28
Total revenue	—			242,026			56,477			(5,849		)	292,654
Operating expenses:
Purchases of natural gas, NGLs and condensate	—			175,551			44,447			(5,849		)	214,149
Direct operating expenses	—			25,180			4,373			—			29,553
Selling, general and administrative expenses	—			21,402			—			—			21,402
Equity compensation expense	—			2,094			—			—			2,094
Depreciation, amortization and accretion expense	—			28,338			1,661			—			29,999
Total operating expenses	—			252,565			50,481			(5,849		)	297,197
Gain on involuntary conversion of property, plant and equipment	—			343			—			—			343
Loss on impairment of property, plant and equipment	—			(18,155		)	—			—			(18,155		)
Operating (loss) income	—			(28,351		)	5,996			—			(22,355		)
Other (expenses) income:
Earnings from consolidated affiliates	(34,123		)	5,363			—			28,760			—
Interest income (expense)	84			(9,375		)	—			—			(9,291		)
Net (loss) income before income tax benefit	(34,039		)	(32,363		)	5,996			28,760			(31,646		)
Income tax benefit	—			495			—			—			495
Net (loss) income from continuing operations	(34,039		)	(31,868		)	5,996			28,760			(31,151		)
Discontinued operations, net of tax	—			(2,255		)	—			—			(2,255		)
Net (loss) income	(34,039		)	(34,123		)	5,996			28,760			(33,406		)
Net income attributable to noncontrolling interests	—			—			633			—			633
Net (loss) income attributable to the Partnership	$	(34,039	)	$	(34,123	)	$	5,363		$	28,760		$	(34,039	)
	Consolidating Statements of Operations
	Year ended December 31, 2012
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Consolidating Adjustments			Consolidated
Revenue	$	—		$	170,569		$	25,441		$	(1,167	)	$	194,843
Unrealized gain on commodity derivatives	—			3,400			—			—			3,400
Total revenue	—			173,969			25,441			(1,167		)	198,243
Operating expenses:
Purchases of natural gas, NGLs and condensate	—			126,649			19,690			(1,167		)	145,172
Direct operating expenses	—			13,895			2,903			—			16,798
Selling, general and administrative expenses	—			14,309			—			—			14,309
Equity compensation expense	—			1,783			—			—			1,783
Depreciation, amortization and accretion expense	—			20,474			810			—			21,284
Total operating expenses	—			177,110			23,403			(1,167		)	199,346
Loss on involuntary conversion of property, plant and equipment	—			(1,021		)	—			—			(1,021		)
Gain on sale of assets, net	—			123			—			—			123
Operating (loss) income	—			(4,039		)	2,038			—			(2,001		)
Other (expenses) income:
Earnings from consolidated affiliates	(6,508		)	1,782			—			4,726			—
Interest expense	—			(4,570		)	—			—			(4,570		)
Net income from continuing operations	(6,508		)	(6,827		)	2,038			4,726			(6,571		)
Discontinued operations	—			319			—			—			319
Net (loss) income	(6,508		)	(6,508		)	2,038			4,726			(6,252		)
Net income attributable to noncontrolling interests	—			—			256			—			256
Net (loss) income attributable to the Partnership	$	(6,508	)	$	(6,508	)	$	1,782		$	4,726		$	(6,508	)
	Consolidated Statements of Comprehensive Income
	Year ended December 31, 2013
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Consolidating Adjustments			Consolidated
Net (loss) income	$	(34,039	)	$	(34,123	)	$	5,996		$	28,760		$	(33,406	)
Unrealized loss on post retirement benefit plan assets and liabilities	(247		)	(247		)	—			247			(247		)
Comprehensive (loss) income	(34,286		)	(34,370		)	5,996			29,007			(33,653		)
Less: Comprehensive income attributable to noncontrolling interests	—			—			633			—			633
Comprehensive (loss) income attributable to the Partnership	$	(34,286	)	$	(34,370	)	$	5,363		$	29,007		$	(34,286	)
	Consolidated Statements of Comprehensive Income
	Year ended December 31, 2012
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Consolidating Adjustments			Consolidated
Net (loss) income	$	(6,508	)	$	(6,508	)	$	2,038		$	4,726		$	(6,252	)
Unrealized loss on post retirement benefit plan assets and liabilities	(64		)	(64		)	—			64			(64		)
Comprehensive (loss) income	(6,572		)	(6,572		)	2,038			4,790			(6,316		)
Less: Comprehensive income attributable to noncontrolling interests	—			—			256			—			$	256
Comprehensive (loss) income attributable to the Partnership	$	(6,572	)	$	(6,572	)	$	1,782		$	4,790		$	(6,572	)
	Statement of Cash Flows
	Year ended December 31, 2013
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Consolidating Adjustments			Consolidated
Net cash provided by operating activities	$	—		$	13,681		$	3,542		—			17,223
Cash flows from investing activities
Additions to property, plant and equipment	—			(26,322		)	(874		)	—			(27,196		)
Proceeds from disposals of property, plant and equipment	—			500			—			—			500
Proceeds from property damage insurance recoveries	—			482			—			—			482
Restricted cash	—			(2,000		)	—			—			(2,000		)
Net contributions from affiliates	43,770			—			—			(43,770		)	—
Net distributions to affiliates	(82,321		)	—			—			82,321			—
Net cash provided by (used in) investing activities	(38,551		)	(27,340		)	(874		)	38,551			(28,214		)
Cash flows from financing activities
Net contributions from affiliates	—			82,321			—			(82,321		)	—
Net distributions to affiliates	—			(42,515		)	(1,255		)	43,770			—
Proceeds from issuance of common units to public, net of offering costs	54,853			—			—			—			54,853
Unitholder contributions	13,075			—			—			—			13,075
Unitholder distributions	(16,120		)	—			—			—			(16,120		)
Issuance of Series A Convertible Preferred Units	14,393			—			—			—			14,393
Unitholder distributions for Blackwater transaction	(27,650		)	—			—			—			(27,650		)
Acquisition of noncontrolling interest	—			—			(752		)	—			(752		)
Net distributions to noncontrolling interest owners	—			—			(661		)	—			(661		)
LTIP tax netting unit repurchase	—			(630		)	—			—			(630		)
Deferred debt issuance costs	—			(2,113		)	—			—			(2,113		)
Payments on other loan	—			(2,640		)	—			—			(2,640		)
Payments on loans to affiliates	—			(20,000		)	—			—			(20,000		)
Borrowings on other debt	—			3,795			—			—			3,795
Payments on bank loans	—			(34,730		)	—			—			(34,730		)
Borrowings on bank loans	—			27,546			—			—			27,546
Payments on long-term debt	—			(131,571		)	—			—			(131,571		)
Borrowings on long-term debt	—			134,021			—			—			134,021
Net cash used in financing activities	$	38,551		$	13,484		$	(2,668	)	$	(38,551	)	10,816
Net decrease in cash and cash equivalents	—			(175		)	—			—			(175		)
Cash and cash equivalents
Beginning of period	1			575			—			—			576
End of period	$	1		$	400		$	—		$	—		$	401
Supplemental cash flow information
Interest payments	$	—		6,416			—			—			$	6,416
Supplemental non-cash information
Decrease in accrued property, plant and equipment	$	—		$	(5,181	)	$	—		$	—		$	(5,181	)
Net assets contributed in the Blackwater Acquisition (See Note 2)	22,121			—			—			—			22,121
Net assets contributed in exchange for the issuance of Series A convertible preferred units (see Note 2)	59,995			—			—			—			59,995
Fair value of Series A Units in excess of net assets received	15,612			—			—			—			15,612
Accrued unitholder distribution for Series A Units	4,811			—			—			—			4,811
	Statement of Cash Flows
	Year ended December 31, 2012
	Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Consolidating Adjustments			Consolidated
Net cash provided by operating activities	$	—		$	16,310		$	2,038		—			18,348
Cash flows from investing activities
Cost of acquisition, net of cash acquired	—			(51,377		)	—			—			(51,377		)
Additions to property, plant and equipment	—			(10,870		)	(835		)	—			(11,705		)
Proceeds from disposals of property, plant and equipment	—			128			—			—			128
Proceeds from property damage insurance recoveries	—			527			—			—			527
Net contributions from affiliates	16,070			—			—			(16,070		)	—
Net distributions to affiliates	(13		)	—			—			13			—
Net cash provided by (used in) investing activities	16,057			(61,592		)	(835		)	(16,057		)	(62,427		)
Cash flows from financing activities
Net contributions from affiliates	—			13			—			(13		)	—
Net distributions to affiliates	—			(15,092		)	(978		)	16,070			—
Unit holder contributions	13			—			—			—			13
Unit holder distributions	(16,070		)	—			—			—			(16,070		)
Net distributions to noncontrolling interest owners	—			—			(225		)	—			(225		)
LTIP tax netting unit repurchase	—			(385		)	—			—			(385		)
Deferred debt issuance costs	—			(1,564		)	—			—			(1,564		)
Payments on long-term debt	—			(59,230		)	—			—			(59,230		)
Borrowings on long-term debt	—			121,245			—			—			121,245
Net cash (used in) provided by financing activities	$	(16,057	)	$	44,987		$	(1,203	)	$	16,057		$	43,784
Net decrease in cash and cash equivalents	—			(295		)	—			—			(295		)
Cash and cash equivalents
Beginning of period	1			870			—			—			871
End of period	$	1		$	575		$	—		$	—		$	576
Supplemental cash flow information
Interest payments	$	—		$	3,185		—			—			$	3,185
Supplemental non-cash information
Increase in accrued property, plant and equipment	$	—		$	6,968		$	—		$	—		$	6,968
Increase in receivables for reimbursable construction in progress projects	—			141			—			—			141

Liquidity_Notes

Liquidity (Notes)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Liquidity	'
	Liquidity
	The principal indicators of our liquidity at December 31, 2013, were our cash on hand and availability under our credit facility. As of December 31, 2013, our available liquidity was $64.9 million, comprised of cash on hand of $0.4 million and $64.5 million available under our credit facility.
	We are required to comply with certain financial covenants and ratios in our credit facility. As of December 31, 2012, the total leverage ratio test, one of the primary financial covenants that we are required to maintain under our credit facility, was not to exceed 4.50 times. At December 31, 2012, our total indebtedness was approximately $128.3 million, which caused our total leverage to EBITDA ratio to be approximately 5.70 to 1.00. As a result, on December 26, 2012, the Partnership entered into the Third Amendment and Waiver to the Partnership's Credit Agreement (the "Credit Agreement"), dated as of December 26, 2012, (the “Third Amendment”). The Third Amendment provided for a waiver of the Partnership's compliance with the Consolidated Total Leverage Ratio with respect to the quarter ending December 31, 2012, and subsequently extended to April 15, 2013. The Third Amendment also required the Partnership to provide certain financial and operating information of the Partnership on a monthly basis for 2013 and for any month after 2013 in which the Consolidated Total Leverage Ratio of the Partnership is in excess of 4.00 to 1.00. The remaining material terms and conditions of the senior secured revolving credit facility, including pricing, maturity and covenants, remained unchanged by the Third Amendment.
	On April 15, 2013, we entered into the Fourth Amendment (the “Fourth Amendment”) to the Credit Agreement. The Fourth Amendment amended the Credit Agreement to (i) allowed for the transactions contemplated under the Contribution Agreement and the issuance of additional Series A Preferred Units as paid-in-kind distributions, (ii) required the Partnership to repay borrowings under the Credit Agreement with the proceeds of certain asset sales and debt issuances, (iii) increased the maximum allowable consolidated total leverage ratio, including allowing for a higher maximum consolidated total leverage ratio for the seven fiscal quarters starting with the second quarter of 2013 and (iv) reset the applicable interest rates for borrowings based on the consolidated total leverage ratio for each quarter. In addition, the Fourth Amendment provides for a decrease in the aggregate commitments under the Credit Agreement from $200 million to $175 million if, on or prior to September 30, 2013, the Partnership has not received from AIM Midstream Holdings a $12.5 million equity contribution and used that contribution to prepay amounts outstanding under the Credit Agreement. On April 15, 2013, we repaid approximately $12.5 million in outstanding borrowings under the credit agreement in connection with the ArcLight Transactions.
	On December 17, 2013, we entered into the Fifth Amendment (the “Fifth Amendment”) to the Credit Agreement. The Fifth Amendment amends the Credit Agreement to, among other things, reflect the acquisition of Blackwater and its subsidiaries pursuant to the Blackwater Merger Agreement. The Fifth Amendment (i) revised the definition of the term “Consolidated EBITDA,” which is used in the calculation of certain financial covenants in the Credit Agreement, to specify how the Consolidated EBITDA of Blackwater would be used to calculate Consolidated EBITDA through the quarter ended on June 30, 2014; (ii) provided that although the Credit Agreement would otherwise require it, Blackwater Maryland, LLC (“Blackwater Maryland”), a subsidiary of Blackwater Holdings, would not be required to deliver any mortgages or deeds of trust on any property of Blackwater Maryland, but that Blackwater Maryland would not grant to any other party any liens on its real property other than liens otherwise permitted by the Credit Agreement; (iii) permitted certain third-party liens to exist on property of Blackwater New Orleans, L.L.C., a subsidiary of Blackwater Holdings; (iv) provided that no more than $20.0 million of borrowings under the Credit Agreement could be used for the payment of the purchase price in connection with the Blackwater Transaction; and (v) required the Partnership and American Midstream, LLC to perform certain covenants after the effective date of the Fifth Amendment to ensure that Blackwater Holdings and its subsidiaries become guarantors of the obligations of the Partnership and American Midstream, LLC under the Credit Agreement and that they secure their obligations and those of the Partnership and American Midstream, LLC under the Credit Agreement with the assets of Blackwater Holdings and its subsidiaries. In addition, the Fifth Amendment removed certain provisions of the Credit Agreement to provide certain financial and operating information of the Partnership on a monthly basis for any month after 2013 in which the Consolidated Total Leverage Ratio of the Partnership is in excess of 4.00 to 1.00.
	As of December 31, 2013 our consolidated total leverage was 3.70, which was in compliance with the consolidated total leverage ratio test in accordance with the leverage covenants as modified in the Fifth Amendment to the credit facility executed on December 17, 2013. As of December 31, 2013, we had approximately $130.7 million of outstanding borrowings under our credit facility and approximately $64.5 million of available borrowing capacity.
	We depend on our credit facility for future capital needs and may use it to fund a portion of cash distributions to unitholders, as necessary, depending on the level of our operating cashflow. The Partnership believes that the consummation of the (i) Blackwater Acquisition, (ii) Equity Restructuring, (iii) Offering and (iv) ArcLight Transactions will allow it to maintain compliance with the consolidated total leverage to EBTIDA required under the facility.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	Subsequent Events
	Distribution
	On January 22, 2014, we announced that the board of directors of our General Partner declared a quarterly cash distribution of $0.4525 per unit for the fourth quarter ended December 31, 2013, or $1.81 per unit on an annualized basis. The cash distribution was paid on February 14, 2014, to unitholders of record as of the close of business on February 7, 2014, together with our General Partner. The ex-dividend date was February 5, 2014.
	Completion of PVA Acquisition
	On January 31, 2014, the Partnership acquired, from Penn Virginia Corporation ("PVA"), approximately 120 miles of high- and low-pressure pipelines ranging from 4 to 8 inches in diameter with over 9,000 horsepower of leased compression, and associated facilities located in the Eagle Ford shale in Gonzales and Lavaca Counties, Texas. The consideration for the PVA Asset Acquisition was financed with the net proceeds of the Partnership’s January 2014 equity offering of $87.3 million and the proceeds from the issuance to our General Partner of 1,168,225 Series B PIK Units representing series B limited partnership interests in the Partnership. The Series B PIK Units have the right to share in distributions from the Partnership on a pro rata basis with holders of the Partnership’s common units and will convert into common units on a one-for-one basis on the second anniversary of the initial issuance The conflicts committee of our General Partner’s board of directors approved the Series B PIK Unit issuance and the transactions contemplated thereby.
	Purchase and Sale Agreement
	In the fourth quarter of 2013, a subsidiary of the Partnership entered into a purchase and sale agreement with Transcontinental Gas Pipe Line Company, LLC ("Transco"), a subsidiary of Williams Partners, LP, to acquire natural gas pipeline facilities for approximately $6.5 million that are contiguous to, and connect with, our High Point system in offshore Louisiana. The closing of the purchase and sale agreement was subject to FERC approval of Transco's application to abandon by sale to us the pipeline facilities and to permit the facilities to serve a gathering function, exempt from FERC's jurisdiction. The FERC granted approval of Transco's application during the first quarter of 2014, and the purchase and sale agreement is expected to close by the end of the first quarter of 2014.

Organization_and_Basis_of_Pres1

Organization and Basis of Presentation (Policies)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'		'
Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]	'		'
			Goodwill and intangible assets
			We record goodwill as the excess of the cost of an acquisition over the fair value of the net assets of the acquired business. Goodwill is not amortized but is reviewed for impairment at least annually or more frequently if an event or change in circumstance indicates that an impairment may have occurred. We first assess qualitative factors to evaluate whether it is more likely than not that an impairment has occurred and it is therefore necessary to perform the two-step goodwill impairment test. If the two-step goodwill impairment test indicates that the goodwill is impaired, an impairment loss is recorded.
			We record the estimated fair value of acquired customer contracts as intangible assets. The intangible assets are amortized over the remaining periods of the customer contracts, which range between 5 months and thirty-five months.
Nature of Business	'		'
	Nature of business
	American Midstream Partners, LP (the “Partnership”), was formed on August 20, 2009 as a Delaware limited partnership for the purpose of operating, developing and acquiring a diversified portfolio of midstream energy assets. We provide natural gas gathering, treating, processing, fractionating, marketing and transportation services primarily in the Gulf Coast and Southeast regions of the United States through our ownership and operation of eleven gathering systems, two processing facilities, one fractionation facility, four terminal sites, three interstate pipelines and five intrastate pipelines. We also own a 50% undivided, non-operating interest in a processing plant located in southern Louisiana. Recently, we became an owner, developer and operator of petroleum, agricultural, and chemical liquid terminal storage facilities.
	We hold our assets in a series of wholly owned limited liability companies as well as a limited partnership. Our capital accounts consist of general partner interests and limited partner interests.
	Our interstate natural gas pipeline assets transport natural gas through the Federal Energy Regulatory Commission (“FERC”) regulated interstate natural gas pipelines in Louisiana, Mississippi, Alabama and Tennessee. Our interstate pipelines include:
	•	High Point Gas Transmission, LLC, which owns and operates approximately 400 miles of intrastate pipeline and is connected to 40 meters with 32 active producers and offers processing options at the Toca processing plant with delivery to Southern Natural Gas available downstream of the processing plant in Louisiana;
	•	American Midstream (Midla), LLC, which owns and operates approximately 370 miles of interstate pipeline that runs from the Monroe gas field in northern Louisiana south through Mississippi to Baton Rouge, Louisiana.
	•	American Midstream (AlaTenn), LLC, which owns and operates approximately 295 miles of interstate pipeline that runs through the Tennessee River Valley from Selmer, Tennessee, to Huntsville, Alabama and serves an eight-county area in Alabama, Mississippi and Tennessee.
Basis of Presentation	'		'
	Basis of presentation
	The accompanying financial statements and related notes present our consolidated financial position as of December 31, 2013 and 2012, and results of operations, comprehensive income, changes in partners' capital and noncontrolling interest, and cash flows for the years ended December 31, 2013, 2012 and 2011.
	We have prepared the consolidated financial statements in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The accompanying consolidated financial statements include accounts of American Midstream Partners, LP, and its controlled subsidiaries. All significant inter-company accounts and transactions have been eliminated in the preparation of the accompanying consolidated financial statements. We have made reclassifications to amounts reported in prior period consolidated financial statements to conform with current year presentation. These reclassifications did not have an impact on net income for the period previously reported.
	The results of operations for acquisitions accounted for as business combinations have been included in the consolidated financial statements since their respective acquisition dates.
Combination of Entities under Common Control, Policy [Policy Text Block]	'		'
	Transactions Between Entities Under Common Control
	We may enter into transactions with our General Partner and affiliates whereby we receive a contribution of midstream assets or subsidiaries in exchange for consideration from the Partnership. We account for the net assets received using the historical book value of the asset or subsidiary being contributed or transferred as these are transactions between entities under common control. Our historical financial statements may be revised to include the results attributable to the assets contributed from our General Partner as if we owned such assets for all periods presented by the Partnership since the change in control of our General Partner, effective April 15, 2013.
Consolidation Policy	'		'
	Consolidation policy
	Our consolidated financial statements include our accounts and those of our subsidiaries in which we have a controlling interest. We hold a 50% undivided interest in the Burns Point gas processing facility in which we are responsible for our proportionate share of the costs and expenses of the facility. Our consolidated financial statements reflect our proportionate share of the revenues, expenses, assets and liabilities of this undivided interest. In July 2012, the Partnership acquired an 87.4% undivided interest in the Chatom Processing and Fractionation facility (the "Chatom System"). In October 2013, the Partnership acquired an additional 4.8% undivided interest in the Chatom System. Our consolidated financial statements reflect the accounts of the Chatom System since acquisition. The interests in the Chatom System held by non-affiliated working interest owners are reflected as noncontrolling interests in the Partnership's consolidated financial statements.
Use of Estimates	'		'
	Use of estimates
	When preparing financial statements in conformity with GAAP, management must make estimates and assumptions based on information available at the time. These estimates and assumptions affect the reported amounts of assets, liabilities, revenues and expenses, as well as the disclosures of contingent assets and liabilities as of the date of the financial statements. Estimates and judgments are based on information available at the time such estimates and judgments are made. Adjustments made with respect to the use of these estimates and judgments often relate to information not previously available. Uncertainties with respect to such estimates and judgments are inherent in the preparation of financial statements. Estimates and judgments are used in, among other things, (i) estimating unbilled revenues, product purchases and operating and general and administrative costs, (ii) developing fair value assumptions, including estimates of future cash flows and discount rates, (iii) analyzing long-lived assets, goodwill and intangible assets for possible impairment, (iv) estimating the useful lives of assets and (v) determining amounts to accrue for contingencies, guarantees and indemnifications. Actual results, therefore, could differ materially from estimated amounts.
Accounting for Regulated Operations	'		'
	Accounting for regulated operations
	Certain of our natural gas pipelines are subject to regulations by FERC. FERC exercises statutory authority over matters such as construction, transportation rates we charge and our underlying accounting practices and ratemaking agreements with customers. Accordingly, we record costs that are allowed in the ratemaking process in a period different from the period in which the costs would be charged to expense by a non-regulated entity. Also, we record assets and liabilities that result from the regulated ratemaking process that would be recorded under GAAP for our regulated entities. As of December 31, 2013 and 2012, we had no such material regulatory assets or liabilities.
Revenue Recognition and the Estimation of Revenues and Cost of Natural Gas	'		'
	Revenue recognition and the estimation of revenues and cost of purchases
	We recognize revenue when all of the following criteria are met: (i) persuasive evidence of an exchange arrangement exists, (ii) delivery has occurred or services have been rendered, (iii) the price is fixed or determinable, and (iv) collectability is reasonably assured. We record revenue and cost of product sold on a gross basis for those transactions where we act as the principal and take title to natural gas, natural gas liquids ("NGLs") or condensates that are purchased for resale. When our customers pay us a fee for providing a service such as gathering, treating, transportation or storage, we record those fees separately in revenues. We have the following arrangements:
	Fee-based
	Under these arrangements, we generally are paid a fixed fee for gathering and transporting natural gas. Fee-based revenues, which are included in sales of natural gas, NGLs and condensate, are recorded when services have been provided, and collectability of the revenue is reasonably assured.
	Percent-of-proceeds, or POP
	Under these arrangements, we generally gather raw natural gas from producers at the wellhead or other supply points, transport it through our gathering system, process it and sell the residue natural gas and NGLs at market prices. Where we provide processing services at the processing plants that we own, or obtain processing service for our own account under our own elective processing arrangements we typically retain and sell a percentage of the residue natural gas and resulting NGLs. We recognize percent-of-proceeds contract revenue, which is included in sales of natural gas, NGLs and condensate, when the natural gas, NGLs or condensate is sold to a purchaser at a fixed or determinable price, delivery has occurred and title has transferred, and collectability of the revenue is reasonably assured.
	Fixed-margin
	Under these arrangements, we purchase natural gas from producers or suppliers at receipt points on our systems at an index price less a fixed transportation fee and simultaneously sell an identical volume of natural gas at delivery points on our systems at the same, undiscounted index price. We recognize revenue from fixed-margin contracts, which is included in sales of natural gas, NGLs and condensate, when the natural gas is sold to a purchaser at a fixed or determinable price, delivery has occurred and title has transferred and collectability of the revenue is reasonably assured.
	Firm transportation
	Under arrangements to provide firm transportation service, we are obligated to transport natural gas nominated by the shipper up to the maximum daily quantity specified in the contract. In exchange for that obligation on our part, the shipper pays a specified reservation charge, whether or not they utilize the capacity. In most cases, the shipper also pays a variable-use charge with respect to quantities actually transported by us. Firm transportation revenue is recorded when products are delivered, services have been provided and collectability of the revenue is reasonably assured.
	Interruptible transportation
	Under arrangements to provide interruptible transportation service, we are only obligated to transport natural gas nominated by the shipper to the extent we have available capacity. For this service the shipper pays no reservation charge but pays a variable-use charge for quantities actually shipped. Interruptible transportation revenue is recorded when products are delivered, services have been provided and collectability of revenue is reasonably assured.
	Interest in the Burns Point Plant
	We account for our interest in the Burns Point Plant using the proportionate consolidation method. Under this method, we include in our consolidated statement of operations our value of plant revenues taken in-kind and plant expenses reimbursed to the operator.
	Terminal revenue and services
	Revenues for our terminals include storage tank lease fees, whereby a customer agrees to pay for a certain amount of tank storage over a certain period of time; and throughput fees, whereby a customer pays a fee based on volumes moving through the terminal. At our terminals, we also offer and provide packaging, blending, handling, filtering and certain other ancillary services. Revenue from firm storage contracts is recognized ratably, which is typically monthly, over the term of the lease. Occasionally, customers pay for tank lease fees in advance. Fees received in advance are deferred until the period they are earned. Revenue from throughput fees and ancillary fees are recognized as services are provided to the customer and when the fees are realizable.
Cash and Cash Equivalents	'		'
	Cash and cash equivalents
	We consider all highly liquid investments with an original maturity of three months or less at the date of purchase to be cash equivalents. The carrying value of cash and cash equivalents approximates fair value because of the short term to maturity of these investments.
Allowance for Doubtful Accounts	'		'
	Allowance for doubtful accounts
	We establish provisions for losses on accounts receivable when we determine that we will not collect all or part of an outstanding balance. Collectability is reviewed regularly and an allowance is established or adjusted, as necessary, using the specific identification method. As of December 31, 2013 and 2012, the Partnership recorded no allowances for losses on accounts receivable.
Inventory	'		'
	Inventory
	Inventory includes NGL product inventory. The Partnership records all product inventories at the lower of cost or market (“LCM”), which is determined on a weighted average basis and included within Other current assets on the consolidated balance sheets. For the years ended December 31, 2013 and 2012, we recorded no lower-of-cost-or-market write-downs on our NGL inventory.
Operational Balancing Agreements and Natural Gas Imbalances	'		'
	Operational balancing agreements and natural gas imbalances
	To facilitate deliveries of natural gas and provide for operational flexibility, we have operational balancing agreements in place with other interconnecting pipelines. These agreements ensure that the volume of natural gas a shipper schedules for transportation between two interconnecting pipelines equals the volume actually delivered. If natural gas moves between pipelines in volumes that are more or less than the volumes the shipper previously scheduled, a natural gas imbalance is created. The imbalances are settled through periodic cash payments or repaid in-kind through future receipt or delivery of natural gas. Natural gas imbalances are recorded as gas imbalances and classified within other current assets or other current liabilities on our consolidated balance sheets based on the market value.
Property, Plant and Equipment	'		'
	Property, plant and equipment
	We capitalize expenditures related to property, plant and equipment that have a useful life greater than one year for (1) assets purchased or constructed; (2) existing assets that are replaced, improved, or the useful lives of which have been extended; and (3) all land, regardless of cost. Maintenance and repair costs, including any planned major maintenance activities, are expensed as incurred.
	We record property, plant, and equipment at its original cost, which we depreciate on a straight-line basis over its estimated useful life. Our determination of the useful lives of property, plant and equipment requires us to make various assumptions, including the supply of and demand for hydrocarbons in the markets served by our assets, normal wear and tear of the facilities, and the extent and frequency of maintenance programs. We record depreciation using the group method of depreciation, which is commonly used by pipelines, utilities and similar assets.
Impairment of Long-Lived Assets	'		'
	Impairment of long lived Assets
	We evaluate the recoverability of our property, plant and equipment when events or circumstances such as economic obsolescence, business climate, legal and other factors indicate we may not recover the carrying amount of the assets. We continually monitor our business, the market, and business environment to identify indicators that could suggest an asset may not be recoverable. We evaluate the asset for recoverability by estimating the undiscounted future cash flows expected to be derived from operating the asset as a going concern. These cash flow estimates require us to make projections and assumptions for many years into the future for pricing, demand, competition, operating cost, contract renewals, and other factors. We recognize an impairment loss when the carrying amount of the asset exceeds its fair value as determined by quoted market prices in active markets or present value techniques. The determination of the fair value using present value techniques requires us to make projections and assumptions regarding future cash flows and weighted average cost of capital. Any changes we make to these projections and assumptions could result in significant revisions to our evaluation of the recoverability of our property, plant and equipment and the recognition of an impairment loss in our consolidated statements of income. We recorded impairments of long-lived assets of $18.2 million for the year ended December 31, 2013. No impairment losses were recognized during the years ended December 31, 2012 and 2011.
Income Taxes	'		'
	Income taxes
	The Partnership is not a taxable entity for U.S. federal income tax purposes or for the majority of states that impose an income tax. Taxes on our net income generally are borne by our unitholders through the allocation of taxable income. However, Blackwater is a taxable entity. We account for income taxes using an asset and liability approach for financial accounting and reporting of income taxes. If it is more than likely that a deferred tax asset will not be realized, a valuation allowance is recognized.
	Certain tax expense results from the enactment of state income tax laws by the State of Texas that apply to entities organized as partnerships and is included in selling, general and administrative expenses in the consolidated statements of operations. The Texas margin tax is computed on our modified gross margin and was not significant for each of the years ended December 31, 2013, 2012 and 2011.
	Net income for financial statement purposes may differ significantly from taxable income allocable to unitholders as a result of differences between the tax basis and financial reporting basis of assets and liabilities and the taxable income allocation requirement under our partnership agreement. The aggregate difference in the basis of our net assets for financial and tax reporting purposes cannot be readily determined because information regarding each partner’s tax attributes in us is not available.
Commitments, Contingencies and Enciornmental Liabilities	'		'
	Commitments, contingencies and environmental liabilities
	We expense or capitalize, as appropriate, expenditures for ongoing compliance with environmental regulations that relate to past or current operations. We expense amounts we incur from the remediation of existing environmental contamination caused by past operations that do not benefit future period by preventing or eliminating future contamination. We record liabilities for environmental matters when assessments indicate that remediation efforts are probable and the costs can be reasonably estimated. Estimates of environmental liabilities are based on currently available facts, existing technology and presently enacted laws and regulation taking into consideration the likely effects of inflation and other factors. These amounts also take into account our prior experience in remediating contaminated sites, other companies’ clean-up experience and data released by government organizations. Our estimates are subject to revision in future periods based on actual cost or new information. We evaluate recoveries from insurance coverage separately from the liability and, when recovery is probable, we record an asset separately from the associated liability in our consolidated financial statements.
	We recognize liabilities for other commitments and contingencies when, after fully analyzing the available information, we determine it is either probable that an asset has been impaired or that a liability has been incurred and the amount of impairment or loss can be reasonably estimated. When a range of probable loss can be estimated, we accrue the most likely amount or if no amount is more likely than another, we accrue the minimum of the range of probable loss. We expense legal costs associated with loss contingencies as such costs are incurred.
	We have legal obligations requiring us to decommission our offshore pipeline systems at retirement. In certain rate jurisdictions, we are permitted to include annual charges for removal costs in the regulated cost of service rates we charge our customers. Additionally, legal obligations exist for a minority of our offshore right-of-way agreements due to requirements or landowner options to compel us to remove the pipe at final abandonment. Sufficient data exists with certain onshore pipeline systems to reasonably estimate the cost of abandoning or retiring a pipeline system. However, in some cases, there is insufficient information to reasonably determine the timing and/or method of settlement of estimating the fair value of the asset retirement obligation. In these cases, the asset retirement obligation cost is considered indeterminate because there is no data or information that can be derived from past practice, industry practice, management’s experience, or the asset’s estimated economic life. The useful lives of most pipeline systems are primarily derived from available supply resources and ultimate consumption of those resources by end users. Variables can affect the remaining lives of the assets which preclude us from making a reasonable estimate of the asset retirement obligation. Indeterminate asset retirement obligation costs will be recognized in the period in which sufficient information exists to reasonably estimate potential settlement dates and methods.
Stockholders' Equity Note, Redeemable Preferred Stock, Issue, Policy [Policy Text Block]	'		'
	Convertible preferred units
	We record the issuance of our Series A Preferred Units at fair value and separately classify these units on our balance sheet in between total liabilities and partners’ capital, frequently called “mezzanine equity” as the ability to exercise these units are outside of the Partnership’s control and contain no beneficial conversion features pursuant to Accounting Standards Codification ("ASC")470-20, Debt with Conversion and Other Options. These units are classified as participating securities and are included in our calculation of net income (loss) per limited and general partner unit using the two-class method.
Asset Retirement Obligations (AROs)	'		'
	Asset retirement obligations (“AROs”)
	AROs are legal obligations associated with the retirement of tangible long-lived assets that result from the asset’s acquisition, construction, development and/or normal operation. An ARO is initially measured at its estimated fair value. Upon initial recognition of an ARO, we record an increase to the carrying amount of the related long-lived asset and an offsetting ARO liability. We depreciate the capitalized ARO using the straight-line method over the period during which the related long-lived asset is expected to provide benefits. After the initial period of ARO recognition, we revise the ARO to reflect the passage of time or revisions to the amount of estimated cash flows or their timing.
Derivative Financial Instruments	'		'
	Derivative financial instruments
	Our net income and cash flows are subject to volatility stemming from changes in interest rates on our variable rate debt, commodity prices and fractionation margins (the relative difference between the price we receive from NGL sales and the corresponding cost of natural gas purchases). In an effort to manage the risks to unitholders, we use a variety of derivative financial instruments including swaps, collars and interest rate caps to create offsetting positions to specific commodity or interest rate exposures. In accordance with the authoritative accounting guidance, we record all derivative financial instruments in our consolidated balance sheets at fair market value. We record the fair market value of our derivative financial instruments in the consolidated balance sheet as current and long-term assets or liabilities on a net basis by counterparty. We record changes in the fair value of our derivative financial instruments in our consolidated statements of operations as follows:
	•	Commodity-based derivatives: “Total revenue”
	•	Corporate interest rate derivatives: “Interest expense”
	Our formal hedging program provides a control structure and governance for our hedging activities specific to identified risks and time periods, which are subject to the approval and monitoring by the board of directors of our general partner. We employ derivative financial instruments in connection with an underlying asset, liability or anticipated transaction, and we do not use derivative financial instruments for speculative or trading purposes.
	The price assumptions we use to value our derivative financial instruments can affect net income for each period. We use published market price information where available, or quotations from over-the-counter, or OTC, market makers to find executable bids and offers. The valuations also reflect the potential impact of conditions, including credit risk of our counterparties. The amounts reported in our consolidated financial statements change quarterly as these valuations are revised to reflect actual results, changes in market conditions or other factors, many of which are beyond our control.
	Our earnings are affected by use of mark-to-market method of accounting as required under GAAP for derivative financial instruments. The use of mark-to-market accounting for derivative financial instruments can cause noncash earnings volatility resulting from changes in the underlying indices, primarily commodity prices.
Comprehensive Income (Loss)	'		'
	Comprehensive income (loss)
	The Partnership’s other comprehensive income (loss) is comprised of adjustments to other post-retirement plan assets and liabilities. See Note 16 "Post-Employment Benefits".
Unit-Based Employee Compensation	'		'
	Unit-based employee compensation
	We award unit-based compensation to management, non-management employees and directors in the form of phantom units, which are deemed to be equity awards. Compensation expense on phantom units is measured by the fair value of the award at the date of grant as determined by management. Compensation expense is recognized in equity compensation expense over the requisite service period of each award. See Note 15 "Long-Term Incentive Plan".
Fair Value Measurements	'		'
	Fair value measurements
	We apply the authoritative accounting provisions for measuring fair value of our derivative instruments and disclosures associated with our outstanding indebtedness. We define fair value as an exit price representing the expected amount we would receive when selling an asset or pay to transfer a liability in an orderly transaction with market participants at the measurement date.
	We use various assumptions and methods in estimating the fair values of our financial instruments. The carrying amounts of cash and cash equivalents, accounts receivable and accounts payable approximated their fair value due to the short-term maturity of these instruments. The carrying amount of our various credit facilities approximate fair value, because the interest rates on these facilities are variable.
	We employ a hierarchy which prioritizes the inputs we use to measure recurring fair value into three distinct categories based upon whether such inputs are observable in active markets or unobservable. We classify assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our methodology for categorizing assets and liabilities that are measured at fair value pursuant to this hierarchy gives the highest priority to unadjusted quoted prices in active markets and the lowest level to unobservable inputs as outlined below:
	•	Level 1 – Inputs represent unadjusted quoted prices in active markets for identical assets or liabilities;
	•	Level 2 – Inputs include quoted prices for similar assets and liabilities in active markets that are either directly or indirectly observable; and
	•	Level 3 – Inputs are unobservable and considered significant to fair value measurement.
	We utilize a mid-market pricing convention, or the “market approach”, for valuation for assigning fair value to our derivative assets and liabilities. Our credit exposure for over-the-counter derivatives is directly with our counterparty and continues until the maturity or termination of the contracts. As appropriate, valuations are adjusted for various factors such as credit and liquidity considerations.
Debt Issuance Costs	'		'
	Debt issuance costs
	Costs incurred in connection with the issuance of long-term debt are deferred and charged to interest expense over the term of the related debt. Gains or losses on debt repurchase and debt extinguishment include any associated unamortized debt issue costs.
Noncontrolling Interest	'		'
	Noncontrolling interest
	Noncontrolling interest represents the noncontrolling interest holders' proportionate share of the equity of the Chatom system. Noncontrolling interest is adjusted for the noncontrolling interest holders' proportionate share of the earnings or losses. Management reports noncontrolling interest in the Chatom system in the financial statements pursuant to paragraph ASC No. 810-10-65-1. The 7.8% noncontrolling interest is held by non-affiliated working interest owners.
Limited Partners' Net Income (Loss) Per Unit	'		'
	Limited partners’ net income (loss) per unit
	We compute limited partners’ net income (loss) per unit by dividing our limited partners’ interest in net income (loss) by the weighted average number of units outstanding during the period. The overall computation, presentation and disclosure of our limited partners’ net income (loss) per unit are made in accordance with the FASB Accounting Standards Codification (ASC) Topic 260 “Earnings per Share”.
New Accounting Pronouncements, Policy [Policy Text Block]	'		'
	Recent accounting pronouncements
	In January 2013, the FASB issued Accounting Standards Update ("ASU") No. 2013-01, Balance Sheet (Topic 210): Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities, which clarifies that ASU 2011-11, Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities, applies to financial instruments or derivative transactions accounted for under ASC 815. The amendments require disclosures to present both gross and net amounts of derivative assets and liabilities that are subject to master netting arrangements with counterparties. We currently present our net derivative assets and liabilities on our statement of financial position. We have provided additional disclosures regarding the gross amounts of derivative assets and liabilities in Note 6 "Derivatives" in accordance with these new standards updates.
	In February 2013, the FASB issued ASU No. 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income ("AOCI"), which requires entities to present either in a single note or parenthetically on the face of the financial statements (i) the amount of significant items reclassified from each component of AOCI and (ii) the income statement line items affected by the reclassifications. We adopted this guidance during the first quarter of 2013; it did not have a material impact on our condensed consolidated financial statements as there are currently no items reclassified from AOCI.
	In July 2013, the FASB issued ASC No. 2013-11, Income Taxes (Topic 740): Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists (a consensus of the FASB Emerging Issues Task Force). This guidance was issued related to the presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss or a tax credit carryforward exists. The updated guidance requires an entity to net its unrecognized tax benefits against the deferred tax assets for all same jurisdiction net operating loss carryforward, a similar tax loss, or tax credit carryforwards. A gross presentation will be required only if such carryforwards are not available or would not be used by the entity to settle any additional income taxes resulting from disallowance of the uncertain tax position. The update is effective prospectively for the Partnership’s fiscal year beginning January 1, 2014 and we are currently evaluating the financial impact.

Acquisitions_Tables

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2013				Dec. 31, 2012							Dec. 31, 2011
Business Acquisition, Pro Forma Information [Abstract]	'				'							'
Unaudited pro forma consolidated information of the partnership, adjusted for the acquisition of the chatom assets	'				'							'
					The following table presents unaudited pro forma consolidated information of the Partnership, adjusted for the acquisition of the Chatom system, as if the acquisition had occurred on January 1, 2011 (in thousands, except per unit amounts):							The following table presents unaudited pro forma consolidated information of the Partnership, adjusted for the acquisition of the Interest in the Plant, as if the acquisition had occurred on January 1, 2011 (in thousands, except per unit amounts):
						Year Ended December 31,							Year Ended
						2012			2011				31-Dec-11
					Revenue	$	246,342		$	296,387		Revenue	$	249,908
					Net loss	(4,319		)	(10,411		)	Net loss	(11,741		)
					Limited partners’ net loss per unit	(0.49		)	(1.53		)	Limited partners’ net loss per unit	(1.65		)
Schedule of recognized identified assets acquired and liabilities assumed	'				'							'
					The following table presents the fair value of consideration transferred to acquire the Chatom system and the amounts of identified assets acquired and liabilities assumed at the acquisition date, as well as the fair value of the 12.6% noncontrolling interest in the Chatom system at the acquisition date (in thousands):
	Cash and cash equivalents	$	1,935
					Cash consideration:	$	51,377
	Accounts receivable	3,629
					Recognized amounts of identifiable assets acquired and liabilities assumed:
	Unbilled revenue	1,446			Unbilled revenue	$	4,535
	Other current assets	2,049			Property, plant and equipment	58,279
	Property, plant and equipment, net	82,615			Asset retirement cost	452
	Other assets	1,000			Accounts payable	(399		)
					Accrued gas purchases	(3,631		)
	Accounts payable	(11		)	Asset retirement obligations	(452		)
	Accrued expenses and other current liabilities	(4,077		)	Noncontrolling interest	(7,407		)
	Current portion of long-term debt	(893		)	Total identifiable net assets:	$	51,377
	Asset retirement obligation liability	(25,763		)
	Total identifiable net assets	$	61,930

Discontinued_Operations_Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	'
		Year Ended December 31,
		2013			2012			2011
	Revenue	$	14,845		$	12,343		$	17,024
	Expense	(14,964		)	(12,024		)	(16,692		)
	Impairment	(2,400		)	—			—
	Loss on sale of assets	(75		)	—			—
	Income tax benefit	339			—			—
	(Loss) income from operations of disposal groups, net of tax	$	(2,255	)	$	319		$	332
	Limited partners' net (loss) income per unit from discontinued operations (basic and diluted)	$	(0.24	)	$	0.03		$	0.04

Concentration_of_Credit_Risk_a1

Concentration of Credit Risk and Trade Accounts Receivable (Tables)	12 Months Ended
	Dec. 31, 2013
Receivables [Abstract]	'
Percentage of revenue earned from major customers	'
	The following table summarizes the percentage of revenue earned from those customers that exceed 10% or greater of the Partnership's consolidated revenue in the consolidated statement of operations for the each of the periods presented below:
		Year Ended December 31,
		2013		2012		2011
	Customer A	28	%	30	%	41	%
	Customer B	13	%	—		—
	Customer C	12	%	13	%	15	%
	Customer D	10	%	14	%	18	%
	Other	37	%	43	%	26	%
	Total	100	%	100	%	100	%
	The following table summarizes the percentage of revenue earned from those customers in each segment that exceed 10% or greater of the Partnership's consolidated segment revenue for the each of the periods presented below:
		Year Ended December 31,
		2013		2012		2011
	Gathering and Processing:
	Customer A	43	%	40	%	55	%
	Customer B	19	%	11	%	—
	Customer D	—		12	%	16	%
	Other	38	%	37	%	29	%
	Total	100	%	100	%	100	%
	Transmission:
	Customer C	39	%	50	%	57	%
	Customer D	16	%	22	%	22	%
	Customer E	—		10	%	—
	Other	45	%	18	%	21	%
	Total	100	%	100	%	100	%
	Terminals:
	Customer F	20	%	—		—
	Customer B	17	%	—		—
	Customer G	16	%	—		—
	Customer H	13	%	—		—
	Other	34	%	—		—
	Total	100	%	—		—

Other_Current_Assets_Tables

Other Current Assets (Tables)	12 Months Ended
	Dec. 31, 2013
Other Current Assets [Abstract]	'
Schedule of other current assets	'
	Other current assets consists of the following (in thousands):
		December 31,
		2013		2012
	Prepaid insurance	$	3,166	$	458
	Other current assets	4,331		2,768
		$	7,497	$	3,226

Derivatives_Tables

Derivatives (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Fair value associated with commodity derivative instruments	'
	As of December 31, 2013 and 2012, the value associated with our commodity derivatives, interest rate swap instrument and weather derivative were recorded in our consolidated balance sheets, under the captions as follows (in thousands):
		Gross Risk Management Assets						Gross Risk Management Liabilities						Net Risk Management Assets (Liabilities)
	Balance Sheet Classification	December 31, 2013			December 31, 2012			December 31, 2013			December 31, 2012			December 31, 2013			December 31, 2012
	Current	$	473		$	1,889		$	—		$	(920	)	$	473		$	969
	Noncurrent	—			—			—			—			—			—
	Total assets	$	473		$	1,889		$	—		$	(920	)	$	473		$	969
	Current	$	27		$	—		$	(450	)	$	—		$	(423	)	$	—
	Noncurrent	—			—			(101		)	—			(101		)	—
	Total liabilities	$	27		$	—		$	(551	)	$	—		$	(524	)	$	—
Realized and unrealized gains (losses) with commodity and interst rate derivative instruments	'
	For the years ended December 31, 2013, 2012 and 2011, the realized and unrealized gains (losses) associated with our commodity, interest rate and weather derivative instruments were recorded in our consolidated statements of operations, under the captions as follows (in thousands):
		Realized			Unrealized
	2013
	Gain (loss) on commodity derivatives	$	1,069		$	(1,041	)
	Interest expense	(207		)	(454		)
	Direct operating expenses	(662		)	—
	Total	$	200		$	(1,495	)
	2012
	Gain (loss) on commodity derivatives	$	2,408		$	992
	Total	$	2,408		$	992
	2011
	Gain (loss) on commodity derivatives	$	(1,911	)	$	(541	)
	Realized loss on early termination of commodity derivatives	(2,998		)	—
	Total	$	(4,909	)	$	(541	)

Fair_Value_Measurement_Tables

Fair Value Measurement (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair value of financial instruments	'
	Fair Value of Financial Instruments
	The following table sets forth by level within the fair value hierarchy, our commodity derivative instruments and interest rate swap, included as part of Risk management assets and Risk management liabilities within the balance sheet, that were measured at fair value on a recurring basis as of December 31, 2013 and 2012 (in thousands):
		Carrying			Estimated Fair Value of the Asset (Liability)
		Amount			Level 1		Level 2			Level 3		Total
	Commodity derivative instruments, net
	31-Dec-13	$	(70	)	$	—	$	(70	)	$	—	$	(70	)
	31-Dec-12	969			—		969			—		969
	Interest rate swap
	31-Dec-13	$	(454	)	$	—	$	(454	)	$	—	$	(454	)
	31-Dec-12	—			—		—			—		—
	The unamortized portion of the premium paid to enter the weather derivative described in Note 6 "Derivatives", is included within Risk management assets on the balance sheet but is not included as part of the above table as it is recorded at amortized carrying cost, not fair value.

Property_Plant_and_Equipment_N1

Property, Plant and Equipment, Net (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, plant, and equipment, net	'
	Property, plant and equipment, net, as of December 31, 2013 and 2012, were as follows (in thousands):
		Useful Life	December 31,			December 31,
		(in years)	2013			2012
	Land	N/A	$	6,015		$	2,254
	Construction in progress	N/A	6,443			5,053
	Base gas	N/A	1,108			—
	Buildings and improvements	4 to 40	5,109			1,432
	Processing and treating plants	8 to 40	97,106			98,106
	Pipelines	5 to 40	239,826			163,447
	Compressors	4 to 20	11,793			8,957
	Dock	20 to 40	7,942			—
	Tanks, truck rack and piping	20 to 40	22,432			—
	Equipment	8 to 20	6,293			4,785
	Computer software	5	3,531			1,950
	Total property, plant and equipment		407,598			285,984
	Accumulated depreciation		(95,088		)	(62,165		)
	Property, plant and equipment, net		$	312,510		$	223,819

Goodwill_and_Intangible_assets1

Goodwill and Intangible assets (Tables)	12 Months Ended
	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]	'
Schedule of Finite-Lived Intangible Assets [Table Text Block]	'
	Intangible assets, net, consist of customer contracts contributed to the Partnership as part of the Blackwater acquisition. The intangible assets are amortized on a straight-line basis over the economic lives of the customer contracts, currently ranging from 5 months to thirty-five months. Intangible assets, net, consist of the following as of December 31, 2013 (in thousands):
		December 31,
		2013
	Customer contracts	$	12,101
	Accumulated amortization	(8,419		)
	Intangible assets, net	$	3,682

Accrued_Expenses_and_Other_Cur1

Accrued Expenses and Other Current Liabilities (Tables)	12 Months Ended
	Dec. 31, 2013
Payables and Accruals [Abstract]	'
Schedule of accrued expenses and other current liabilities	'
	Accrued expenses and other current liabilities were as follows (in thousands):
		December 31,
		2013		2012
	Accrued expenses	$	5,906	$	6,519
	Gas imbalances payable	4,305		971
	Other accrued expenses and other current liabilities	4,847		2,129
		$	15,058	$	9,619

Asset_Retirement_Obligation_Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Schedule of reconciliation of the beginning and ending aggregate carrying amount of ARO liabilities	'
	The following table is a reconciliation of the asset retirement obligations (in thousands):
		Year Ended December 31,
		2013			2012
	Beginning asset retirement obligation	$	8,319		$	8,093
	Liabilities assumed	25,763			452
	Expenditures	—			(258		)
	Accretion expense	554			32
	Ending asset retirement obligation	$	34,636		$	8,319
	For the periods indicated, total expenses related to operating leases, asset retirement obligations, land site leases and right-of-way agreements were (in thousands):
			Year Ended December 31,
			2013			2012		2011
	Operating leases		$	1,051		$	941	$	803
	ARO		554			32		1,393
			$	1,605		$	973	$	2,196

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Outstanding borrowings under the credit facility	'
	Our outstanding borrowings under the credit facility at December 31, 2013 and 2012, respectively, were (in thousands):
		December 31,
		2013		2012
	Revolving credit facility	$	130,735	$	128,285
	Other debt	2,048		—
	Total debt	132,783		128,285
	Less: current portion	2,048		—
	Long-term debt	$	130,735	$	128,285

Partners_Capital_Tables

Partners' Capital (Tables)	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Schedule for number of units outstanding	'
	The numbers of units outstanding as of December 31, 2013, 2012 and 2011, respectively, were as follows (in thousands):
		December 31,
		2013	2012	2011
	Series A convertible preferred units	5,279	—	—
	Limited partner common units	7,414	4,639	4,561
	Limited partner subordinated units	—	4,526	4,526
	General partner units	185	185	185

Earnings_per_Unit_Tables

Earnings per Unit (Tables)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'
Schedule of Earnings Per Share, Basic and Diluted, Per General and Limited Partner Unit, Including Two Class Method [Table Text Block]	'
	We determined basic and diluted net income (loss) per general partner unit and limited partner unit as follows, (in thousands, except per unit amounts):
		Year Ended December 31,
		2013			2012			2011
	Net loss from continuing operations	$	(31,151	)	$	(6,571	)	$	(12,030	)
	Net income attributable to noncontrolling interests	633			256			—
	Net loss from continuing operations attributable to the Partnership	(31,784		)	(6,827		)	(12,030		)
	Less:
	Distributions on Series A Preferred Units	24,117			—			—
	General partner's distributions	464			322			864
	General partner's share in undistributed loss	(1,708		)	(458		)	(1,112		)
	Blackwater net loss from continuing operations	(716		)	—			—
	Net loss from continuing operations available to limited partners	(53,941		)	(6,691		)	(11,782		)
	Net (loss) income from discontinued operations available to limited partners	(1,893		)	313			325
	Net loss available to limited partners	$	(55,834	)	$	(6,378	)	$	(11,457	)
	Weighted average number of units used in computation of limited partners’ net loss per unit (basic and diluted)	7,981			9,113			6,997
	Limited partners’ net loss from continuing operations per unit (basic and diluted)	$	(6.76	)	$	(0.73	)	$	(1.68	)
	Limited partners’ net loss (income) from discontinued operations per unit (basic and diluted)	(0.24		)	0.03			0.04
	Limited partners’ net loss per unit (basic and diluted)	$	(7.00	)	$	(0.70	)	$	(1.64	)

LongTerm_Incentive_Plan_Tables

Long-Term Incentive Plan (Tables)	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Summarizes unit-based awards	'
	The following table summarizes our unit-based awards for each of the periods indicated, in units:
		Year Ended December 31,
		2013		2012		2011
	Outstanding at beginning of period	90,938		162,860		205,864
	Granted	114,336		38,595		19,414
	Forfeited	(18,320	)	(12,517	)	—
	Vested	(111,425	)	(98,000	)	(62,418	)
	Outstanding at end of period	75,529		90,938		162,860
	Fair value per unit	$13.36 to $25.60		$14.70 to $21.40		$14.70 to $19.69

PostEmployment_Benefits_Tables

Post-Employment Benefits (Tables)	12 Months Ended
	Dec. 31, 2013
Compensation and Retirement Disclosure [Abstract]	'
Schedule of changes in the benefit obligation, the fair value of the plan assets and the recorded asset or liability of the OPEB Plan using the accrual method	'
	The tables below detail the changes in the benefit obligation, the fair value of the plan assets and the recorded asset or liability of the OPEB Plan using the accrual method (in thousands):
			Year Ended December 31,
			2013				2012				2011
	Change in benefit obligation
	Benefit obligation, beginning of period		$	472			$	466			$	869
	Service cost		5				4				3
	Interest cost		15				18				22
	Actuarial (gain) loss		(29		)		22				(367		)
	Plan amendments		126				—				—
	Benefits paid		(57		)		(38		)		(61		)
	Benefit obligation, end of period		$	532			$	472			$	466
	Change in plan assets
	Fair value of plan assets, beginning of period		$	1,552			$	1,432			$	1,319
	Actual return on plan assets		(53		)		84				99
	Employer’s contributions		90				90				90
	Benefits paid		(61		)		(54		)		(76		)
	Fair value of plan assets, end of period		$	1,528			$	1,552			$	1,432
	Funded status
	Funded status		$	996			$	1,080			$	966
Schedule of amounts of plan assets recognized in consolidated balance sheets	'
	The weighted average asset allocation of our OPEB Plan at the measurement date by asset category, which are all classified as Level 1 investments, are as follows:
			December 31,
			2013			2012			2011
	Fixed income (a)		70.1	%		72.2	%		72.1	%
	Cash and short term assets (b)		29.9	%		27.8	%		27.9	%
	Total		100	%		100	%		100	%
	(a)	United States government securities, municipal corporate bonds and notes and asset backed securities
	(b)	Cash and securities with maturities of one year or less
	The amounts of plan assets recognized in our consolidated balance sheets were as follows (in thousands):
			December 31,
			2013				2012				2011
	Other assets		$	996			$	1,080			$	966
Schedule of components of net periodic benefit cost and other amounts recognized in other comprehensive income	'
	Components of Net Periodic (Benefit) Cost and Other amounts Recognized in Other Comprehensive Income (in thousands):
			Year Ended December 31,
			2013				2012				2011
	Net Periodic (Benefit) Cost
	Service cost		$	5			$	4			$	3
	Interest cost		15				18				22
	Expected return on plan assets		(70		)		(67		)		(60		)
	Amortization of net (gain) loss		(23		)		(43		)		(47		)
	Net periodic (benefit) cost		$	(73	)		$	(88	)		$	(82	)
	Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income
	Net loss (gain)		$	247			$	64			$	(359	)
	Total recognized in other comprehensive income		247				64				(359		)
	Total recognized in net periodic benefit cost and other comprehensive income		$	174			$	(24	)		$	(441	)
Schedule of assumptions made in measuremnet of the projected benefit obligations or assets of the OPEB Plan	'
	The assumptions made in measurement of the projected benefit obligations or assets of the OPEB Plan were as follows:
			Year Ended December 31,
			2013			2012			2011
	Discount rate		4.57	%		3.42	%		3.96	%
	Expected return on plan assets		4.5	%		4.5	%		4.5	%
	Health care trend rate		4.5	%		3	%		3	%
Schedule of benefits expected to be paid in each of the next five fiscal years	'
	The following table presents the benefits expected to be paid in each of the next five fiscal years, and in the aggregate for the five years thereafter by the OPEB Plan (in thousands):
	For the year ending
	2014	$	28
	2015	29
	2016	28
	2017	27
	2018	27
	Five years thereafter	157

Income_Tax_Tables

Income Tax (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	'
	An analysis of the Partnership’s deferred taxes is as follows (in thousands):
		31-Dec-13
	Deferred tax assets:
	Net operating loss carryforwards	$	5,455
	Other	182
	Total deferred tax assets	5,637
	Deferred tax liabilities:
	Property, plant and equipment	9,022
	Intangible assets	1,364
	Total deferred tax liabilities	10,386
	Deferred income tax liability, net	$	(4,749	)
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	'
	The details of the provision for taxes on income for the year ended December 31, 2013, are as follows (in thousands):
		Year Ended December 31, 2013
	Net loss before income tax benefit	(31,646		)
	Federal statutory rate	34		%
	Federal income tax benefit at statutory rate	10,760
	Reconciling items:
	Partnership loss not subject to income tax	(10,350		)
	Income not subject to corporate-level tax	222
	State and local tax benefit	71
	Return to provision true-ups	(175		)
	Other	(33		)
	Income tax benefit	$	495
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	'
	The income tax provision related to continuing operations consist of the following (in thousands):
		Year Ended December 31, 2013
	Current income tax	$	—
	Deferred income tax benefit	495
	Effective income tax rate	1.6		%

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Future non-cancelable commitments related to certain contractual obligations	'
	Future non-cancelable commitments related to certain contractual obligations as of December 31, 2013, are presented below (in thousands):
		Payments Due by Period
		Total			2014			2015			2016		2017		2018		Thereafter
	Operating leases and service contracts	$	6,149		$	959		$	1,012		$	814	$	810	$	584	$	1,970
	ARO	34,636			—			—			7,867		—		—		26,769
	Total	$	40,785		$	959		$	1,012		$	8,681	$	810	$	584	$	28,739
Total expenses related to operating leases, asset retirement obligations, land site leases and right-of-way agreements	'
	The following table is a reconciliation of the asset retirement obligations (in thousands):
		Year Ended December 31,
		2013			2012
	Beginning asset retirement obligation	$	8,319		$	8,093
	Liabilities assumed	25,763			452
	Expenditures	—			(258		)
	Accretion expense	554			32
	Ending asset retirement obligation	$	34,636		$	8,319
	For the periods indicated, total expenses related to operating leases, asset retirement obligations, land site leases and right-of-way agreements were (in thousands):
			Year Ended December 31,
			2013			2012			2011
	Operating leases		$	1,051		$	941		$	803
	ARO		554			32			1,393
			$	1,605		$	973		$	2,196

Reporting_Segments_Tables

Reporting Segments (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segment information for the periods	'
	The following tables set forth our segment information for the periods indicated (in thousands):
		Year Ended December 31, 2013
		Gathering				Transmission				Terminals (a)			Total
		and
		Processing
	Total revenue	$	192,446			$	90,377			$	9,831		$	292,654
	Less:
	COMA Income	689				154				—			843
	Unrealized loss on commodity derivatives	(1,041		)		—				—			(1,041		)
	Purchases of natural gas, NGL's and condensate	156,334				57,815				—			214,149
	Direct operating expenses	—				—				2,080			2,080
	Segment gross margin (a)	36,464				32,408				7,751			76,623
	Direct operating expenses	(14,214		)		(13,259		)		—			(27,473		)
	COMA Income												843
	Unrealized loss on commodity derivatives												(1,041		)
	Selling, general and administrative expenses												(21,402		)
	Equity compensation expense												(2,094		)
	Depreciation, amortization and accretion expense												(29,999		)
	Gain on involuntary conversion of property, plant and equipment												343
	Loss on impairment of property, plant and equipment												(18,155		)
	Interest expense												(9,291		)
	Income tax benefit												495
	Loss from operations of disposal groups, net of tax												(2,255		)
	Net loss												(33,406		)
	Less: Net income attributable to non-controlling interests												633
	Net loss attributable to the Partnership												$	(34,039	)
	(a)	Terminals segment amounts are for the period from April 15, 2013 to December 31, 2013.
		Year Ended December 31, 2012
		Gathering				Transmission				Total
		and
		Processing
	Total revenue	$	145,714			$	52,529			$	198,243
	Less:
	COMA Income	673				2,700				3,373
	Unrealized gain on commodity derivatives	992				—				992
	Purchases of natural gas, NGL's and condensate	108,656				36,516				145,172
	Segment gross margin (a)	35,393				13,313				48,706
	Direct operating expenses	(11,767		)		(5,031		)		(16,798		)
	COMA Income									3,373
	Unrealized gain on commodity derivatives									992
	Selling, general and administrative expenses									(14,309		)
	Equity compensation expense									(1,783		)
	Depreciation, amortization and accretion expense									(21,284		)
	Loss on involuntary conversion of property, plant and equipment									(1,021		)
	Gain on sale of assets, net									123
	Interest expense									(4,570		)
	Income from operations of disposal groups									319
	Net loss									(6,252		)
	Less: Net income attributable to non-controlling interests									256
	Net loss attributable to the Partnership									$	(6,508	)
		Year Ended December 31, 2011
		Gathering				Transmission				Total
		and
		Processing
	Total revenue	$	160,953			$	66,766			$	227,719
	Less:
	Realized loss on early termination of commodity derivatives	(2,998		)		—				(2,998		)
	Unrealized loss on commodity derivatives	(541		)		—				(541		)
	Purchases of natural gas, NGL's and condensate	134,369				53,029				187,398
	Segment gross margin (a)	30,123				13,737				43,860
	Direct operating expenses	(6,199		)		(5,220		)		(11,419		)
	Realized loss on early termination of commodity derivatives									(2,998		)
	Unrealized loss on commodity derivatives									(541		)
Selling, general and administrative expenses									(11,082		)
Advisory services agreement termination fee									(2,500		)
Transaction expenses									—
Equity compensation expense									(3,357		)
Depreciation, amortization and accretion expense									(20,449		)
Gain on acquisition of assets									565
Loss on sale of assets, net									399
Interest expense									(4,508		)
Income from operations of disposal groups									332
Net loss attributable to the Partnership									$	(11,698	)
(a)	Segment gross margin for our Gathering and Processing segment consists of revenue less purchases of natural gas, NGLs and condensate and COMA. Segment gross margin for our Transmission segment consists of revenue, less purchases of natural gas and COMA. Segment gross margin for our Terminals segment consists of revenue, less direct operating expenses. Gross margin consists of the sum of the segment gross margin amounts for each of these segments. As an indicator of our operating performance, gross margin should not be considered an alternative to, or more meaningful than, net income or cash flow from operations as determined in accordance with GAAP. Our gross margin may not be comparable to a similarly titled measure of another company because other entities may not calculate gross margin in the same manner. Effective October 1, 2012, we changed our segment gross margin measure to exclude construction, operating and maintenance agreement (“COMA”) income. Effective January 1, 2011, we changed our segment gross margin measure to exclude unrealized non-cash mark-to-market adjustments related to our commodity derivatives. Effective April 1, 2011, we changed our segment gross margin measure to exclude realized early termination costs on commodity derivatives.
For a definition of gross margin and a reconciliation to its most directly comparable financial measure calculated and presented in accordance with GAAP and a discussion of how we use gross margin to evaluate our operating performance, please read Item 7. "Management's Discussion and Analysis, How We Evaluate Our Operations”.
Percentage of revenue earned from major customers	'
	The following table summarizes the percentage of revenue earned from those customers that exceed 10% or greater of the Partnership's consolidated revenue in the consolidated statement of operations for the each of the periods presented below:
		Year Ended December 31,
		2013			2012			2011
	Customer A	28	%		30	%		41	%
	Customer B	13	%		—			—
	Customer C	12	%		13	%		15	%
	Customer D	10	%		14	%		18	%
	Other	37	%		43	%		26	%
	Total	100	%		100	%		100	%
	The following table summarizes the percentage of revenue earned from those customers in each segment that exceed 10% or greater of the Partnership's consolidated segment revenue for the each of the periods presented below:
		Year Ended December 31,
		2013			2012			2011
	Gathering and Processing:
	Customer A	43	%		40	%		55	%
	Customer B	19	%		11	%		—
	Customer D	—			12	%		16	%
	Other	38	%		37	%		29	%
	Total	100	%		100	%		100	%
	Transmission:
	Customer C	39	%		50	%		57	%
	Customer D	16	%		22	%		22	%
	Customer E	—			10	%		—
	Other	45	%		18	%		21	%
	Total	100	%		100	%		100	%
	Terminals:
	Customer F	20	%		—			—
	Customer B	17	%		—			—
	Customer G	16	%		—			—
	Customer H	13	%		—			—
	Other	34	%		—			—
	Total	100	%		—			—

Quarterly_Financial_Data_Table

Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule of Quarterly Financial Information [Table Text Block]	'
	Summarized unaudited quarterly financial data for 2013 and 2012 are as follows (in thousands, except per unit amounts):
		First			Second			Third			Fourth
		Quarter (a)			Quarter			Quarter			Quarter
	Year Ended December 31, 2013
	Total revenues	$	59,402		$	77,608		$	79,536		$	76,108
	Gross margin (b)	12,476			19,158			21,380			23,609
	Operating (loss) income	(1,740		)	(17,780		)	(210		)	(2,625		)
	Net loss from continuing operations	(3,471		)	(19,996		)	(2,632		)	(5,052		)
	Income (loss) from operations of disposal groups	73			(1,930		)	91			(489		)
	Net income attributable to noncontrolling interest	155			188			190			100
	Net loss attributable to the Partnership	(3,553		)	(22,114		)	(2,731		)	(5,641		)
	General partner’s interest in net loss	(70		)	(905		)	(221		)	(209		)
	Limited partners’ interest in net loss	$	(3,483	)	$	(21,209	)	$	(2,510	)	$	(5,432	)
	Limited partners’ (loss) income per unit:
	Loss from continuing operations	$	(0.39	)	$	(4.00	)	$	(0.82	)	$	(1.55	)
	Income (loss) from discontinued operations	0.01			(0.20		)	0.02			(0.07		)
	Net loss	$	(0.38	)	$	(4.20	)	$	(0.80	)	$	(1.62	)
	Year Ended December 31, 2012
	Total revenues	$	44,857		$	43,322		$	53,401		$	56,663
	Gross margin (b)	12,560			11,253			12,979			11,914
	Operating income (loss)	2,417			3,077			(2,513		)	(4,982		)
	Net income (loss) from continuing operations	1,660			2,252			(4,014		)	(6,469		)
	Income (loss) from operations of disposal groups	31			75			(12		)	225
	Net income (loss) attributable to noncontrolling interest	—			—			249			7
	Net income (loss) attributable to the Partnership	1,691			2,327			(4,275		)	(6,251		)
	General partner’s interest in net income (loss)	34			46			(85		)	(124		)
	Limited partners’ interest in net income (loss)	$	1,657		$	2,281		$	(4,190	)	$	(6,127	)
	Limited partners’ income (loss) per unit:
	Income (loss) from continuing operations	$	0.18		$	0.24		$	(0.46	)	$	(0.69	)
	Income (loss) from discontinued operations	—			0.01			—			0.02
	Net income (loss)	$	0.18		$	0.25		$	(0.46	)	$	(0.67	)
	(a)	During the fourth quarter of 2012, we identified revenues in the amount of $0.3 million associated with proceeds received in connection with COMA reimbursable projects that were incorrectly recognized in the first quarter of 2012 that should have been recognized ratably during each of the succeeding quarters of 2012 for approximately $0.1 million per quarter. In addition, we recorded in the first quarter of 2012 and for the year ended December 31, 2012, out-of-period adjustments amounting to $0.1 million for the correction of immaterial errors associated with additional depreciation expense and selling, general and administrative expense. Based upon our evaluation of relevant factors, we concluded that these errors were not material to any previously issued and current consolidated financial statements.
	(b)	For a definition of gross margin and a reconciliation to its most directly comparable financial measure calculated and presented in accordance with GAAP and a discussion of how we use gross margin to evaluate our operating performance, please read Item 7. "Management's Discussion and Analysis, How We Evaluate Our Operations”.

Subsidiary_Guarantors_Tables

Subsidiary Guarantors (Tables)	12 Months Ended
	Dec. 31, 2013
Subsidiary Guarantors [Abstract]	'
Schedule of Condensed Consolidating Balance Sheet	'
		Consolidating Balance Sheet
		31-Dec-12
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Consolidating Adjustments			Consolidated
	Assets
	Current assets
	Cash and cash equivalents	$	1		$	575		$	—		$	—		$	576
	Accounts receivable	—			1,612			346			—			1,958
	Unbilled revenue	—			18,102			3,410			—			21,512
	Risk management assets	—			969			—			—			969
	Other current assets	—			2,967			259			—			3,226
	Total current assets	1			24,225			4,015			—			28,241
	Property, plant and equipment, net	—			165,001			58,818			—			223,819
	Investment in subsidiaries	80,164			51,613			—			(131,777		)	—
	Other assets, net	—			4,636			—			—			4,636
	Total assets	$	80,165		$	245,475		$	62,833		$	(131,777	)	$	256,696
	Liabilities and Partners’ Capital
	Current liabilities
	Accounts payable	$	—		$	5,100		$	427		$	—		$	5,527
	Accrued gas purchases	—			14,606			2,428			—			17,034
	Accrued expenses and other current liabilities	—			9,150			469			—			9,619
	Total current liabilities	—			28,856			3,324			—			32,180
	Asset retirement obligations	—			7,861			458			—			8,319
	Other liabilities	—			309			—			—			309
	Long-term debt	—			128,285			—			—			128,285
	Total liabilities	—			165,311			3,782			—			169,093
	Partners' capital
	Total partners' capital	80,165			80,164			51,613			(131,777		)	80,165
	Noncontrolling interest	—			—			7,438			—			7,438
	Total equity	80,165			80,164			59,051			(131,777		)	87,603
	Total liabilities and partners' capital	$	80,165		$	245,475		$	62,833		$	(131,777	)	$	256,696
Schedule of Condensed Consolidating Statements of Operations	'
		Consolidating Statements of Operations
		Year ended December 31, 2012
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Consolidating Adjustments			Consolidated
	Revenue	$	—		$	170,569		$	25,441		$	(1,167	)	$	194,843
	Unrealized gain on commodity derivatives	—			3,400			—			—			3,400
	Total revenue	—			173,969			25,441			(1,167		)	198,243
	Operating expenses:
	Purchases of natural gas, NGLs and condensate	—			126,649			19,690			(1,167		)	145,172
	Direct operating expenses	—			13,895			2,903			—			16,798
	Selling, general and administrative expenses	—			14,309			—			—			14,309
	Equity compensation expense	—			1,783			—			—			1,783
	Depreciation, amortization and accretion expense	—			20,474			810			—			21,284
	Total operating expenses	—			177,110			23,403			(1,167		)	199,346
	Loss on involuntary conversion of property, plant and equipment	—			(1,021		)	—			—			(1,021		)
	Gain on sale of assets, net	—			123			—			—			123
	Operating (loss) income	—			(4,039		)	2,038			—			(2,001		)
	Other (expenses) income:
	Earnings from consolidated affiliates	(6,508		)	1,782			—			4,726			—
	Interest expense	—			(4,570		)	—			—			(4,570		)
	Net income from continuing operations	(6,508		)	(6,827		)	2,038			4,726			(6,571		)
	Discontinued operations	—			319			—			—			319
	Net (loss) income	(6,508		)	(6,508		)	2,038			4,726			(6,252		)
	Net income attributable to noncontrolling interests	—			—			256			—			256
	Net (loss) income attributable to the Partnership	$	(6,508	)	$	(6,508	)	$	1,782		$	4,726		$	(6,508	)
Schedule of Condensed Consolidating Statements of Cash Flow	'
		Statement of Cash Flows
		Year ended December 31, 2012
		Parent			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Consolidating Adjustments			Consolidated
	Net cash provided by operating activities	$	—		$	16,310		$	2,038		—			18,348
	Cash flows from investing activities
	Cost of acquisition, net of cash acquired	—			(51,377		)	—			—			(51,377		)
	Additions to property, plant and equipment	—			(10,870		)	(835		)	—			(11,705		)
	Proceeds from disposals of property, plant and equipment	—			128			—			—			128
	Proceeds from property damage insurance recoveries	—			527			—			—			527
	Net contributions from affiliates	16,070			—			—			(16,070		)	—
	Net distributions to affiliates	(13		)	—			—			13			—
	Net cash provided by (used in) investing activities	16,057			(61,592		)	(835		)	(16,057		)	(62,427		)
	Cash flows from financing activities
	Net contributions from affiliates	—			13			—			(13		)	—
	Net distributions to affiliates	—			(15,092		)	(978		)	16,070			—
	Unit holder contributions	13			—			—			—			13
	Unit holder distributions	(16,070		)	—			—			—			(16,070		)
	Net distributions to noncontrolling interest owners	—			—			(225		)	—			(225		)
	LTIP tax netting unit repurchase	—			(385		)	—			—			(385		)
	Deferred debt issuance costs	—			(1,564		)	—			—			(1,564		)
	Payments on long-term debt	—			(59,230		)	—			—			(59,230		)
	Borrowings on long-term debt	—			121,245			—			—			121,245
	Net cash (used in) provided by financing activities	$	(16,057	)	$	44,987		$	(1,203	)	$	16,057		$	43,784
	Net decrease in cash and cash equivalents	—			(295		)	—			—			(295		)
	Cash and cash equivalents
	Beginning of period	1			870			—			—			871
	End of period	$	1		$	575		$	—		$	—		$	576
	Supplemental cash flow information
	Interest payments	$	—		$	3,185		—			—			$	3,185
	Supplemental non-cash information
	Increase in accrued property, plant and equipment	$	—		$	6,968		$	—		$	—		$	6,968
	Increase in receivables for reimbursable construction in progress projects	—			141			—			—			141

Organization_and_Basis_of_Pres2

Organization and Basis of Presentation (Details) (USD $)

3 Months Ended

12 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

3 Months Ended

0 Months Ended

12 Months Ended

9 Months Ended

Dec. 31, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 05, 2014

Sep. 30, 2013

Aug. 08, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 31, 2014

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 17, 2013

Dec. 31, 2013

Dec. 31, 2013

Apr. 15, 2013

Dec. 31, 2013

Dec. 31, 2013

Jul. 02, 2012

Feb. 05, 2014

Feb. 05, 2014

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2013

counties

counties

General Partner [Member]

Partnership Interest [Member]

Partnership Interest [Member]

Partnership Interest [Member]

High Point [Member]

High Point [Member]

HPGT System [Member]

Midla system [Member]

AlaTenn system [Member]

ArcLight [Member]

Terminals [Member]

Burns Point Plant [Member]

High Point [Member]

High Point [Member]

High Point [Member]

Chatom processing, gathering and fractionation plant [Member]

Chatom processing, gathering and fractionation plant [Member]

AIM Midstream Holdings [Member]

High Point [Member]

High Point [Member]

AIM Midstream Holdings [Member]

Fourth Amendment [Member]

General Partner [Member]

Minimum [Member]

Maximum [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

Meters

mi

mi

ft

bbl

mi

ArcLight [Member]

Series A [Member]

Partnership Interest [Member]

Revolving Credit Facility [Member]

ArcLight [Member]

Producers

Gas_Receipt_Point

Issuance of Preferred Units [Member]

High Point [Member]

Series A [Member]

mi

Repayment of Debt [Member]

Collaborative Arrangements and Non-collaborative Arrangement Transactions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Finite-Lived Intangible Asset, Useful Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'0 years 5 months 0 days

'0 years 35 months 0 days

'

'

'

Impairment of Long-Lived Assets Held-for-use

($3,000,000)

($15,200,000)

($100,000)

($18,155,000)

$0

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unit holder contributions

'

'

'

13,075,000

13,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gathering pipeline (miles)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

400

370

295

'

'

'

700

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Natural Gas Collection Receipt Points

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

75

'

'

'

'

'

'

'

'

'

'

'

'

'

Counties in which entity operates, Alabama, Mississippi, and Tennessee (counties)

8

'

'

8

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquired interest (percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

100.00%

'

4.80%

87.40%

'

'

'

'

'

'

'

'

'

'

'

Contributed capital

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,142,857

'

'

'

'

'

'

'

'

Water depth of natural gas collection receipt points, maximum (feet)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners

7.80%

'

'

7.80%

'

'

'

12.60%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of meters

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of producers

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

32

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partnership cancellation of subordinated units (percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90.00%

'

'

'

'

'

'

'

Total Consideration for Issuance of Preferred Units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Transaction Expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,500,000

'

'

'

'

'

'

'

'

Payments on long-term debt

'

'

'

-131,571,000

-59,230,000

-120,670,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-12,500,000

'

'

'

'

'

'

Other Ownership Interests, Units Outstanding

'

'

'

'

'

'

'

'

'

'

0

4,526,066

4,526,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive Distribution Right Allocation

'

'

'

'

'

'

'

'

'

14.98%

'

'

'

100.00%

85.02%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive Distribution Right, After Minimum Quarterly Distributions, Percent

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

48.00%

'

'

'

'

'

Incentive Distribution, Distribution Per Unit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.41

'

'

'

'

'

Million barrels of storage capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Escrow Deposit

'

'

'

'

'

'

'

'

12,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Contributions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$12,500,000

$13,000

$12,500,000

Partners' Capital Account, Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.00%

95.00%

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Number of Securities Called by Warrants or Rights

'

'

'

'

'

'

300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Exercise Price of Warrants or Rights

'

'

'

'

'

'

0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisitions_Consideration_Tra

Acquisitions (Consideration Transferred) (Details) (USD $)

3 Months Ended

9 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 15, 2013

Dec. 31, 2013

Apr. 15, 2013

Dec. 31, 2013

Apr. 15, 2013

Sep. 30, 2013

Dec. 31, 2013

Jul. 02, 2012

Dec. 01, 2011

Dec. 31, 2013

Dec. 01, 2011

Dec. 17, 2013

Jul. 10, 2013

Dec. 31, 2013

Dec. 17, 2013

Apr. 15, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

High Point [Member]

High Point [Member]

Terminals [Member]

Terminals [Member]

Chatom processing, gathering and fractionation plant [Member]

Chatom processing, gathering and fractionation plant [Member]

Chatom processing, gathering and fractionation plant [Member]

Plant operator, enterprise gas processing, llc [Member]

Burns point plant [Member]

Burns point plant [Member]

Blackwater [Member]

Blackwater [Member]

Terminals [Member]

Terminals [Member]

Total Partners Capital

Total Partners Capital

Total Partners Capital

Total Partners Capital

Total Partners Capital

Total Partners Capital

Total Partners Capital

Limited Partner [Member]

Limited Partner [Member]

Limited Partner [Member]

Limited Partner [Member]

Series A [Member]

Issuance of Preferred Units [Member]

Fourth Amendment [Member]

AIM Midstream Holdings [Member]

mi

mi

acre

bbl

Blackwater [Member]

Blackwater [Member]

Blackwater [Member]

Blackwater [Member]

High Point [Member]

Revolving Credit Facility [Member]

Partnership Interest [Member]

Series A [Member]

Repayment of Debt [Member]

High Point [Member]

Series A [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Cash and Cash Equivalents

'

'

'

'

'

'

'

'

'

'

'

'

$1,935,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Consideration for Issuance of Preferred Units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acreage acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Million barrels of storage capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Cost of Acquired Entity, Purchase Price

6,500,000

'

'

'

'

'

'

'

'

6,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

63,900,000

2,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash consideration

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Bargain purchase (gain)

'

'

'

'

'

'

'

'

'

0

0

-565,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash consideration:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

51,377,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unbilled revenue

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,535,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Property, plant and equipment

312,510,000

'

'

'

223,819,000

'

'

'

'

312,510,000

223,819,000

'

'

'

'

'

'

'

'

58,279,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset retirement cost

-34,636,000

'

'

'

-8,319,000

'

'

'

'

-34,636,000

-8,319,000

-8,093,000

'

'

'

'

'

'

'

-452,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accounts payable

-3,261,000

'

'

'

-5,527,000

'

'

'

'

-3,261,000

-5,527,000

'

'

'

'

'

'

'

'

-399,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued gas purchases

-16,394,000

'

'

'

-17,034,000

'

'

'

'

-16,394,000

-17,034,000

'

'

'

'

'

'

'

'

-3,631,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset retirement obligation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-452,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Noncontrolling interest

4,628,000

'

'

'

7,438,000

'

'

'

'

4,628,000

7,438,000

'

'

'

'

'

'

'

'

-7,407,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total identifiable net assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

51,377,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquired interest (percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

4.80%

87.40%

50.00%

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Chatom assets location

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current capacity of the refrigeration processing plant

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fractionation unit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,900

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-ton per day sulfur recovery

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

160

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gas gathering system

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

29

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-controlling interest

7.80%

12.60%

'

'

'

'

'

'

12.60%

7.80%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Assumed cost of capital

'

'

'

'

'

'

'

'

9.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Inflationary cost

'

'

'

'

'

'

'

'

2.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Effective income tax rate, continuing operations

'

'

'

'

'

'

'

'

35.00%

0.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Effective income tax rate reconciliation, state and local income taxes

'

'

'

'

'

'

'

'

6.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of outstanding noncontrolling interest acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

38.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Noncontrolling Interest, Ownership Percentage by Parent

92.20%

'

'

'

'

'

'

'

'

92.20%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenues

76,108,000

79,536,000

77,608,000

59,402,000

56,663,000

53,401,000

43,322,000

44,857,000

'

292,654,000

198,243,000

227,719,000

'

30,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net loss attributable to the Partnership

-5,641,000

-2,731,000

-22,114,000

-3,553,000

-6,251,000

-4,275,000

2,327,000

1,691,000

'

-34,039,000

-6,508,000

-11,698,000

'

7,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-34,039,000

-6,508,000

-11,698,000

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Distributions

'

'

'

'

'

'

'

'

'

-27,650,000

322,000

864,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

22,251,000

16,070,000

43,546,000

27,650,000

0

0

21,628,000

15,748,000

42,682,000

3,052,000

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Assets (Liabilities), Net

'

'

'

'

'

'

'

'

'

'

'

'

61,930,000

'

'

'

22,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Distributions to Existing Interest

'

'

'

'

'

'

'

'

'

15,612,000

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,612,000

'

'

'

'

'

'

15,300,000

'

'

'

'

'

'

'

Units issued in business acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

125,500

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenue

'

'

'

'

'

'

'

'

'

292,626,000

194,843,000

233,169,000

'

'

'

'

'

'

'

'

'

'

'

'

'

9,831,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Income (Loss), Including Portion Attributable to Noncontrolling Interest

'

'

'

'

'

'

'

'

'

-33,406,000

-6,252,000

-11,698,000

'

'

'

-800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-32,634,000

'

'

'

'

'

'

'

Gathering pipeline (miles)

'

'

'

'

'

'

'

'

'

'

'

'

'

700

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Units, Contributed Capital

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,142,857

'

'

Transaction Expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,500,000

'

'

Payments on long-term debt

'

'

'

'

'

'

'

'

'

-131,571,000

-59,230,000

-120,670,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-12,500,000

'

Partnership cancellation of subordinated units (percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90.00%

Distribution Made to Member or Limited Partner, Distributions Paid, Conversion Price Per Unit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$17.50

'

'

'

Temporary Equity, Carrying Amount, Including Portion Attributable to Noncontrolling Interests

94,811,000

'

'

'

0

'

'

'

'

94,811,000

0

'

90,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Accounts Receivable

'

'

'

'

'

'

'

'

'

'

'

'

3,629,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Unbilled Revenues

'

'

'

'

'

'

'

'

'

'

'

'

1,446,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Other Assets, Current

'

'

'

'

'

'

'

'

'

'

'

'

2,049,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Property, Plant and Equipment

'

'

'

'

'

'

'

'

'

'

'

'

82,615,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Other Assets, Noncurrent

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Accounts Payable

'

'

'

'

'

'

'

'

'

'

'

'

11,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Accrued Expenses and Other Assets, Current

'

'

'

'

'

'

'

'

'

'

'

'

4,077,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Debt, Current

'

'

'

'

'

'

'

'

'

'

'

'

893,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Asset Retirement Obligation

'

'

'

'

'

'

'

'

'

'

'

'

$25,763,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisitions_Pro_Forma_Informa

Acquisitions (Pro Forma Information) (Details) (USD $)

3 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Apr. 15, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Jul. 02, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 01, 2011

Dec. 01, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

High Point [Member]

High Point [Member]

Chatom processing, gathering and fractionation plant [Member]

Chatom processing, gathering and fractionation plant [Member]

Chatom processing, gathering and fractionation plant [Member]

Chatom processing, gathering and fractionation plant [Member]

Burns Point Plant [Member]

Burns Point Plant [Member]

Burns Point Plant [Member]

Plant Operator Enterprise Gas Processing LLC [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

mi

Chatom processing, gathering and fractionation plant [Member]

Chatom processing, gathering and fractionation plant [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenue

'

'

'

'

'

'

'

'

$292,626,000

$194,843,000

$233,169,000

'

'

'

'

'

'

'

'

'

'

'

$25,441,000

$56,080,000

$246,342,000

Gas Receipt Points

'

'

'

'

'

'

'

'

'

'

'

700

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain (loss) on acquisition of assets

'

'

'

'

'

'

'

'

0

0

565,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquired interest (percent)

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

4.80%

87.40%

'

50.00%

'

50.00%

'

'

'

'

Revenues

76,108,000

79,536,000

77,608,000

59,402,000

56,663,000

53,401,000

43,322,000

44,857,000

292,654,000

198,243,000

227,719,000

30,400,000

'

'

'

'

'

'

'

'

'

56,477,000

25,441,000

'

'

Business Acquisition, Cost of Acquired Entity, Cash Paid

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35,500,000

'

'

'

'

'

Business Combination, Pro Forma Information [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenue

'

'

'

'

'

'

'

'

'

'

'

'

'

'

296,387,000

'

'

249,908,000

'

'

'

'

'

'

'

Net loss attributable to the Partnership

-5,641,000

-2,731,000

-22,114,000

-3,553,000

-6,251,000

-4,275,000

2,327,000

1,691,000

-34,039,000

-6,508,000

-11,698,000

7,200,000

'

'

'

'

'

'

'

'

'

'

1,782,000

5,363,000

-4,319,000

Net loss

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$10,411,000

'

'

$11,741,000

'

'

'

'

'

'

'

Limited partnersb net loss per unit

'

'

'

'

'

'

'

'

'

'

'

'

'

-0.49

-1.53

'

'

-1.65

'

'

'

'

'

'

'

Discontinued_Operations_Detail

Discontinued Operations (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Disposal Group, Including Discontinued Operation, Revenue	'	'	'	'	'	'	'	'	$14,845,000	$12,343,000	$17,024,000
Disposal Group, Including Discontinued Operation, Operating Expense	'	'	'	'	'	'	'	'	-14,964,000	-12,024,000	-16,692,000
Disposal Group, Including Discontinued Operation, Impairment	'	'	'	'	'	'	'	'	-2,400,000	0	0
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax	'	'	'	'	'	'	'	'	-75,000	0	0
Discontinued Operation, Tax Effect of Discontinued Operation	'	'	'	'	'	'	'	'	339,000	0	0
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic and Diluted Share	'	'	'	'	'	'	'	'	($0.24)	$0.03	$0.04
Unbilled revenue	22,005,000	'	'	'	21,512,000	'	'	'	22,005,000	21,512,000	'
Noncurrent assets held for sale, net	1,914,000	'	'	'	0	'	'	'	1,914,000	0	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	1,106,000	'	'	'	0	'	'	'	1,106,000	0	'
Loss on impairment of noncurrent assets held for sale	600,000	'	1,800,000	'	'	'	'	'	2,400,000	0	0
Fair Value Inputs, Discount Rate	'	'	10.00%	'	'	'	'	'	0.00%	'	'
Assets Held-for-sale, Current	1,268,000	'	'	'	0	'	'	'	1,268,000	0	'
Property, plant and equipment	312,510,000	'	'	'	223,819,000	'	'	'	312,510,000	223,819,000	'
Gas Purchase Payable, Current	16,394,000	'	'	'	17,034,000	'	'	'	16,394,000	17,034,000	'
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	-489,000	91,000	-1,930,000	73,000	225,000	-12,000	75,000	31,000	-2,255,000	319,000	332,000
Income (Loss) from Discontinued Operations, Net of Tax, Per Outstanding Limited Partnership Unit, Basic	-0.07	0.02	-0.2	0.01	0.02	0	0.01	0	'	'	'
Current Fiscal Year End Date	'	'	'	'	'	'	'	'	'--12-31	'	'
Income Approach Valuation Technique [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'	'	'	'	'	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Fair Value Inputs, Thoughput Volume Decline Rate	'	'	2.50%	'	'	'	'	'	'	'	'
Blackwater [Member]	'	'	'	'	'	'	'	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent assets held for sale, net	1,600,000	'	'	'	'	'	'	'	1,600,000	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	100,000	'	'	'	'	'	'	'	100,000	'	'
Assets Held-for-sale, Current	100,000	'	'	'	'	'	'	'	100,000	'	'
Gathering And Processing [Member]	'	'	'	'	'	'	'	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent assets held for sale, net	300,000	'	'	'	'	'	'	'	300,000	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	1,100,000	'	'	'	'	'	'	'	1,100,000	'	'
Assets Held-for-sale, Current	$1,200,000	'	'	'	'	'	'	'	$1,200,000	'	'

Concentration_of_Credit_Risk_a2

Concentration of Credit Risk and Trade Accounts Receivable (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Revenue, Major Customer	'	'	'
Entity-wide revenue by major customer, percentage	100.00%	100.00%	100.00%
Customer A [Member]	'	'	'
Revenue, Major Customer	'	'	'
Entity-wide revenue by major customer, percentage	28.00%	30.00%	41.00%
Customer B [Member]	'	'	'
Revenue, Major Customer	'	'	'
Entity-wide revenue by major customer, percentage	13.00%	0.00%	0.00%
Cusotmer C [Member]	'	'	'
Revenue, Major Customer	'	'	'
Entity-wide revenue by major customer, percentage	12.00%	13.00%	15.00%
Customer D [Member]	'	'	'
Revenue, Major Customer	'	'	'
Entity-wide revenue by major customer, percentage	10.00%	14.00%	18.00%
Customer Other [Member]	'	'	'
Revenue, Major Customer	'	'	'
Entity-wide revenue by major customer, percentage	37.00%	43.00%	26.00%

Other_Current_Assets_Details

Other Current Assets (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Other Current Assets [Abstract]	'	'
Prepaid insurance	$3,166	$458
Other current assets	4,331	2,768
Other current assets	$7,497	$3,226

Derivatives_Fair_Value_of_Comm

Derivatives (Fair Value of Commodity Derivatives) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Risk management assets and Risk management liabilities	'	'
Derivative Asset, Fair Value, Net	$473,000	$969,000
Derivative Liability, Fair Value, Net	-524,000	0
Interest Rate Swap [Member]	'	'
Derivative [Line Items]	'	'
Notional Amount of Interest Rate Derivatives	100,000,000	'
Commodity derivatives [Member]	'	'
Risk management assets and Risk management liabilities	'	'
Derivative asset, gross derivative asset	473,000	1,889,000
Derivative asset, gross derivative liabilities	0	-920,000
Derivative liability, gross derivative assets	27,000	0
Derivative liability, gross derivative liabilities	-551,000	0
Commodity derivatives [Member] | Risk Management Assets [Member]	'	'
Risk management assets and Risk management liabilities	'	'
Derivative asset, gross derivative asset	473,000	1,889,000
Derivative asset, gross derivative liabilities	0	-920,000
Derivative Asset, Fair Value, Net	473,000	969,000
Commodity derivatives [Member] | Risk Management Assets - Long Term [Member]	'	'
Risk management assets and Risk management liabilities	'	'
Derivative asset, gross derivative asset	0	0
Derivative asset, gross derivative liabilities	0	0
Derivative Asset, Fair Value, Net	0	0
Commodity derivatives [Member] | Risk Management Liabilities [Member]	'	'
Risk management assets and Risk management liabilities	'	'
Derivative liability, gross derivative assets	27,000	0
Derivative liability, gross derivative liabilities	-450,000	0
Derivative Liability, Fair Value, Net	-423,000	0
Commodity derivatives [Member] | Risk Management Liabilities - Long Term [Member]	'	'
Risk management assets and Risk management liabilities	'	'
Derivative liability, gross derivative assets	0	0
Derivative liability, gross derivative liabilities	-101,000	0
Derivative Liability, Fair Value, Net	($101,000)	$0

Derivatives_Realized_and_Unrea

Derivatives (Realized and Unrealized Gains (Losses)) (Details) (USD $)

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Commodity derivatives [Member]

Commodity derivatives [Member]

Commodity derivatives [Member]

Commodity derivatives [Member]

Commodity derivatives [Member]

Commodity derivatives [Member]

Commodity derivatives [Member]

Commodity derivatives [Member]

Commodity derivatives [Member]

Gathering And Processing [Member]

Gathering And Processing [Member]

Gathering And Processing [Member]

Revenue [Member]

Unrealized Gain (Loss) on Derivatives [Member]

Unrealized Gain (Loss) on Derivatives [Member]

Unrealized Gain (Loss) on Derivatives [Member]

Interest Expense [Member]

Other Income [Member]

Derivatives, Fair Value [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain (loss) on derivatives, realized

$0

$0

($2,998)

$200

$2,408

($4,909)

($1,911)

$1,069

$2,408

($2,998)

($207)

($662)

'

'

'

Gain (loss) on derivatives, unrealized

($1,041)

$992

($541)

($1,495)

$992

($541)

($541)

'

$992

$0

($454)

$0

($1,041)

$992

($541)

Derivatives_Details_Textual

Derivatives (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2013
Derivative [Line Items]	'
Aggregate notional volume of our commodity derivative	2,900,000
Interest Rate Swap [Member]	'
Derivative [Line Items]	'
Notional Amount of Interest Rate Derivatives	$100,000,000
Weather Contract [Member]	'
Derivative [Line Items]	'
Derivative Instruments Not Designated as Hedging Instruments, Potential Cash Proceeds from Contract	10,000,000
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	0
Payments of Derivative Issuance Costs	1,100,000
Derivative, Term of Contract	'0 years 12 months 0 days
Derivative Issuance Costs	$500,000

Fair_Value_Measurement_Fair_Va

Fair Value Measurement (Fair Value of Financial Instruments) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Interest Rate Swap [Member]	'	'
Quantitative Information about Level 3 Fair Value Measurements	'	'
Carrying Amount	'	$0
Estimated Fair Value	-454	'
Interest Rate Swap [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Quantitative Information about Level 3 Fair Value Measurements	'	'
Estimated Fair Value	-454	0
Interest Rate Swap [Member] | Level 1 [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Quantitative Information about Level 3 Fair Value Measurements	'	'
Estimated Fair Value	0	0
Interest Rate Swap [Member] | Level 2 [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Quantitative Information about Level 3 Fair Value Measurements	'	'
Estimated Fair Value	-454	0
Interest Rate Swap [Member] | Level 3 [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Quantitative Information about Level 3 Fair Value Measurements	'	'
Estimated Fair Value	0	0
Commodity Contract [Member]	'	'
Quantitative Information about Level 3 Fair Value Measurements	'	'
Carrying Amount	'	969
Estimated Fair Value	-70	'
Commodity Contract [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Quantitative Information about Level 3 Fair Value Measurements	'	'
Estimated Fair Value	-70	969
Commodity Contract [Member] | Level 1 [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Quantitative Information about Level 3 Fair Value Measurements	'	'
Estimated Fair Value	0	0
Commodity Contract [Member] | Level 2 [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Quantitative Information about Level 3 Fair Value Measurements	'	'
Estimated Fair Value	-70	969
Commodity Contract [Member] | Level 3 [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Quantitative Information about Level 3 Fair Value Measurements	'	'
Estimated Fair Value	$0	$0

Fair_Value_Measurement_Changes

Fair Value Measurement (Changes in Level 3 Fair Value Measurements) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Changes in Level 3 Fair Value Measurements	'	'	'
Realized gain (loss) on early termination of commodity derivatives	$0	$0	($2,998,000)
Unrealized gain (loss) on commodity derivatives	28,000	3,400,000	-2,452,000
Transfers out of Level 3	'	($1,000,000)	'

Fair_Value_Measurement_Details

Fair Value Measurement (Details Textual) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2012
Fair Value Disclosures [Abstract]	'
Transfers out of Level 3	$1

Property_Plant_and_Equipment_N2

Property, Plant and Equipment, Net (Details) (USD $)	3 Months Ended			12 Months Ended
	Dec. 31, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Property, Plant and Equipment [Line Items]	'	'	'	'	'	'
Fair Value Inputs, Discount Rate	'	10.00%	'	0.00%	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	$407,598,000	'	'	$407,598,000	$285,984,000	'
Accumulated depreciation	-95,088,000	'	'	-95,088,000	-62,165,000	'
Property, plant and equipment, net	312,510,000	'	'	312,510,000	223,819,000	'
Interest Costs Capitalized	'	'	'	200,000	0	'
Depreciation	'	'	'	25,900,000	21,400,000	'
Impairment of Long-Lived Assets Held-for-use	-3,000,000	-15,200,000	-100,000	-18,155,000	0	0
Loss on impairment of noncurrent assets held for sale	600,000	1,800,000	'	2,400,000	0	0
Land [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	6,015,000	'	'	6,015,000	2,254,000	'
Construction in progress [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	6,443,000	'	'	6,443,000	5,053,000	'
Base Gas [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	1,108,000	'	'	1,108,000	0	'
Buildings and improvements [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	5,109,000	'	'	5,109,000	1,432,000	'
Processing and treating plants [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	97,106,000	'	'	97,106,000	98,106,000	'
Pipelines [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	239,826,000	'	'	239,826,000	163,447,000	'
Compressors [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	11,793,000	'	'	11,793,000	8,957,000	'
Dock [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	7,942,000	'	'	7,942,000	'	'
Dock [Member] [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	'	'	'	'	0	'
Tanks, truck rack and piping [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	22,432,000	'	'	22,432,000	0	'
Equipment [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	6,293,000	'	'	6,293,000	4,785,000	'
Computer software [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	3,531,000	'	'	3,531,000	1,950,000	'
Minimum [Member] | Buildings and improvements [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment in useful life	'4 years	'	'	'	'	'
Minimum [Member] | Processing and treating plants [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment in useful life	'8 years	'	'	'	'	'
Minimum [Member] | Pipelines [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment in useful life	'5 years	'	'	'	'	'
Minimum [Member] | Compressors [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment in useful life	'4 years	'	'	'	'	'
Minimum [Member] | Equipment [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment in useful life	'8 years	'	'	'	'	'
Maximum [Member] | Buildings and improvements [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment in useful life	'40 years	'	'	'	'	'
Maximum [Member] | Processing and treating plants [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment in useful life	'40 years	'	'	'	'	'
Maximum [Member] | Pipelines [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment in useful life	'40 years	'	'	'	'	'
Maximum [Member] | Compressors [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment in useful life	'20 years	'	'	'	'	'
Maximum [Member] | Equipment [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment in useful life	'20 years	'	'	'	'	'
Maximum [Member] | Computer software [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment in useful life	'5 years	'	'	'	'	'
Ala Tenn System [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Property plant and equipment gross	$100,500,000	'	'	$100,500,000	$26,100,000	'
Income Approach Valuation Technique [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'	'	'	'
Property, Plant and Equipment, Net [Abstract]	'	'	'	'	'	'
Fair Value Inputs, Thoughput Volume Decline Rate	'	2.50%	'	'	'	'

Property_Plant_and_Equipment_N3

Property, Plant and Equipment, Net (Issuance Proceeds) (Details) (USD $)	3 Months Ended			12 Months Ended
	Dec. 31, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Property, Plant and Equipment [Abstract]	'	'	'	'	'	'
Insurance settlements receivable	'	'	'	$1,100,000	'	'
Cash flows from investing activities	'	600,000	500,000	482,000	527,000	0
Impairment of Long-Lived Assets Held-for-use	-3,000,000	-15,200,000	-100,000	-18,155,000	0	0
Gain (loss) on involuntary conversion of property, plant and equipment	'	'	$400,000	$343,000	($1,021,000)	$0

Goodwill_and_Intangible_assets2

Goodwill and Intangible assets (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Goodwill [Line Items]	'	'
Goodwill	$16,447	$0

Goodwill_and_Intangible_assets3

Goodwill and Intangible assets Schedule of intangible assets (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Finite-Lived Intangible Assets [Line Items]	'	'
Amortization of Intangible Assets	$3,700,000	'
Customer contracts	12,101,000	'
Accumulated amortization	-8,419,000	'
Intangible Assets, Net (Excluding Goodwill)	3,682,000	0
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months	2,700,000	'
Finite-Lived Intangible Assets, Amortization Expense, Year Two	$1,000,000	'
Minimum [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Finite-Lived Intangible Asset, Useful Life	'0 years 5 months 0 days	'
Maximum [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Finite-Lived Intangible Asset, Useful Life	'0 years 35 months 0 days	'

Accrued_Expenses_and_Other_Cur2

Accrued Expenses and Other Current Liabilities (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Payables and Accruals [Abstract]	'	'
Accrued expenses	$5,906	$6,519
Gas imbalances payable	4,305	971
Other accrued expenses and other current liabilities	4,847	2,129
Accrued expenses and other current liabilities	$15,058	$9,619

Asset_Retirement_Obligation_De

Asset Retirement Obligation (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligaiton [Line Items]	'	'
Restricted Cash and Cash Equivalents	$3,000,000	'
Balance at beginning of period	34,636,000	8,319,000
Additions	25,763,000	452,000
Expenditures	0	-258,000
Accretion expense	554,000	32,000
Balance at end of period	$8,319,000	$8,093,000

LongTerm_Debt_Outstanding_Borr

Long-Term Debt (Outstanding Borrowings) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
Line of Credit Facility, Amount Outstanding	$130,735	$128,285
Revolving credit facility	130,735	128,285
Other Long-term Debt	2,048	0
Long-term Debt	132,783	128,285
Long-term Debt, Current Maturities	$2,048	$0

LongTerm_Debt_Textual_Details

Long-Term Debt (Textual) (Details) (USD $)

12 Months Ended

0 Months Ended

12 Months Ended

9 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Apr. 15, 2013

Dec. 31, 2013

Apr. 15, 2013

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Apr. 15, 2013

Maximum [Member]

Maximum [Member]

Federal Funds [Member]

Eurodollar [Member]

Revolving Credit Facility [Member]

Insurance Premium Financing [Member]

Repayment of Debt [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

Fiscal Quarter Ending December 31, 2014 [Member]

Fiscal Quarter Ending December 31, 2014 [Member]

Fiscal Quarter Ending December 31, 2014 [Member]

Fiscal Quarter Ending December 31, 2014 [Member]

Fiscal Quarter Ending December 31, 2014 [Member]

Fourth Amendment [Member]

Series A [Member]

ArcLight [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Base Rate [Member]

Base Rate [Member]

Eurodollar [Member]

Eurodollar [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Amount Outstanding Limit

$200,000,000

'

'

'

'

'

'

$175,000,000

'

'

'

'

'

'

'

'

'

$200,000,000

Basis spread on variable rate

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

1.50%

3.75%

2.50%

4.75%

'

Line of Credit Facility, Unused Capacity, Commitment Fee Percentage

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Facility fee (percent)

'

'

'

'

'

0.50%

1.00%

'

3.95%

'

'

'

'

'

'

'

'

'

Debt, weighted average interest rate

4.53%

4.09%

6.71%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Coverage Ratio

2.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letters of credit outstanding amount

4,800,000

2,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt issuance cost

6,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ratio of indebtedness to net capital

3.7

5.7

'

5.75

4,500

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Amount Outstanding

130,735,000

128,285,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Remaining Borrowing Capacity

64,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from (Payments for) Other Financing Activities

2,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Periodic Payment

300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments on long-term debt

-131,571,000

-59,230,000

-120,670,000

'

'

'

'

'

'

-12,500,000

'

'

'

'

'

'

'

'

Partners' Capital Account, Contributions

'

'

'

'

'

'

'

'

'

'

$12,500,000

$13,000

$12,500,000

'

'

'

'

'

Partners_Capital_Units_Outstan

Partners' Capital (Units Outstanding) (Details)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Limited partner common units	7,414,000	9,165,000	'
General partner units	185,000	185,000	'
Preferred Units, Outstanding	5,279,000	'	'
AIM Midstream Holdings No. of units outstanding [Member]	'	'	'
Limited partner common units	7,414,000	4,639,000	4,561,000
Limited partner subordinated units	0	4,526,066	4,526,000
General partner units	185,000	185,000	185,000
Preferred Units, Outstanding	5,279,000	0	0

Partners_Capital_Details_Textu

Partners Capital (Details Textual) (USD $)

3 Months Ended

6 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

Jun. 30, 2013

Jun. 30, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 05, 2014

Aug. 08, 2013

Apr. 15, 2013

Apr. 15, 2013

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Feb. 05, 2014

Feb. 05, 2014

Apr. 15, 2013

Mar. 31, 2014

Jan. 22, 2014

Apr. 15, 2013

Dec. 31, 2013

Apr. 15, 2013

Apr. 15, 2013

Sep. 30, 2013

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 15, 2013

Apr. 15, 2013

Total Partners Capital

Total Partners Capital

Total Partners Capital

General Partner Interest

General Partner Interest

General Partner Interest

General Partner [Member]

AIM Midstream Holdings [Member]

High Point [Member]

High Point [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Series A [Member]

Series A [Member]

Series A [Member]

Issuance of Preferred Units [Member]

ArcLight [Member]

General Partner [Member]

High Point [Member]

High Point [Member]

Partnership Interest [Member]

Partnership Interest [Member]

Partnership Interest [Member]

High Point [Member]

Fourth Amendment [Member]

Partnership Interest [Member]

Cash Distribution [Member]

Series A [Member]

General Partner Interest

Revolving Credit Facility [Member]

AIM Midstream Holdings [Member]

High Point [Member]

Repayment of Debt [Member]

Series A [Member]

Subsidiary, Sale of Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General partner interest

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Limited partner interest

'

'

98.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Limited Partners' Capital Account, Units Issued

'

'

2,568,712

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Sale of Stock, Price Per Share

'

'

$22.47

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General partner units

'

'

185,000

185,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

185,000

185,000

185,000

'

'

Earned and paid (usd per unit)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.25

'

'

'

'

'

'

'

'

'

'

Incentive Distribution Right, After Minimum Quarterly Distributions, Percent

'

'

'

'

'

'

'

'

'

'

'

'

'

'

48.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partnership cancellation of subordinated units (percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Consideration for Issuance of Preferred Units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$15,000,000

'

Contributed capital

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,142,857

'

'

'

'

'

'

'

'

'

Other Ownership Interests, Units Outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

4,526,066

4,526,000

'

'

Incentive Distribution Right Allocation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

14.98%

100.00%

85.02%

'

'

'

'

'

Incentive Distribution, Distribution Per Unit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.41

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Number of Securities Called by Warrants or Rights

'

'

'

'

'

300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Exercise Price of Warrants or Rights

'

'

'

'

'

0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Escrow Deposit

'

'

'

'

'

'

12,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Contributions

'

'

'

'

'

'

'

'

'

12,500,000

'

12,500,000

13,000

'

'

'

'

'

'

'

'

'

'

'

12,500,000

'

'

'

'

'

'

'

'

Partners' Capital Account, Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.00%

95.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Transaction Expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,500,000

'

'

'

'

'

'

'

'

'

Payments on long-term debt

'

'

-131,571,000

-59,230,000

-120,670,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-12,500,000

Distribution Made to Member or Limited Partner, Distributions Declared, Per Unit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.45

$1.81

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution Made to Member or Limited Partner, Distributions Paid, Conversion Price Per Unit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$17.50

'

'

'

'

'

'

'

'

'

'

'

'

Temporary Equity, Carrying Amount, Including Portion Attributable to Noncontrolling Interests

'

'

94,811,000

0

'

'

'

90,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Assets (Liabilities), Net

'

'

'

'

'

'

'

61,930,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Distributions to Existing Interest

'

'

15,612,000

0

0

'

'

'

15,612,000

'

'

312,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value Inputs, Discount Rate

10.00%

'

0.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.00%

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value input, distribution growth rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.00%

'

'

'

'

'

'

'

'

'

'

'

Fair value, paid in kind distributions

'

'

$25.17

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution Made to Member or Limited Partner, Payment In Kind Declared

'

'

4,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value input, option value

'

'

7.27

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Public Sale of Units Net of Offering Costs

'

'

($54,853,000)

$0

($69,085,000)

'

'

'

'

$54,853,000

$69,085,000

$0

'

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners Capital (Textual) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of agragate limited partner interest

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earnings_per_Unit_Details

Earnings per Unit (Details) (USD $)	3 Months Ended								12 Months Ended
Share data in Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	($5,052,000)	($2,632,000)	($19,996,000)	($3,471,000)	($6,469,000)	($4,014,000)	$2,252,000	$1,660,000	($31,151,000)	($6,571,000)	($12,030,000)
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	633,000	256,000	'
Net income attributable to noncontrolling interests	100,000	190,000	188,000	155,000	7,000	249,000	0	0	'	'	'
Income (Loss) from Continuing Operations Attributable to Parent	'	'	'	'	'	'	'	'	-31,784,000	-6,827,000	-12,030,000
Distribution Made to Member or Limited Partner, Cash Distributions Declared	'	'	'	'	'	'	'	'	24,117,000	0	0
Distribution Made to Member or Limited Partner, Payment In Kind Declared	'	'	'	'	'	'	'	'	4,800,000	'	'
Partners' Capital Account, Distributions to Existing Interest	'	'	'	'	'	'	'	'	15,612,000	0	0
Partners' Capital Account, Distributions	'	'	'	'	'	'	'	'	-27,650,000	322,000	864,000
Distribution Made to Member or Limited Partner, Cash Distributions Paid	'	'	'	'	'	'	'	'	464,000	'	'
General Partners' Capital Account, Period Undistributed Income (Loss) From Continuing Operations, Amount	'	'	'	'	'	'	'	'	1,708,000	458,000	1,112,000
Net Income (Loss) From Continuing Operatins, Attributable to Limited Partners	'	'	'	'	'	'	'	'	-53,941,000	-6,691,000	-11,782,000
Income (loss) from Discontinued Operations, Net of Tax, Available to Limited Partners	'	'	'	'	'	'	'	'	-1,893,000	313,000	325,000
Net Income (Loss) Allocated to Limited Partners	-5,432,000	-2,510,000	-21,209,000	-3,483,000	-6,127,000	-4,190,000	2,281,000	1,657,000	-55,834,000	-6,378,000	-11,457,000
Weighted Average Number of Shares Outstanding, Basic and Diluted	'	'	'	'	'	'	'	'	7,981	9,113	6,997
Income (Loss) from Continuing Operations, Per Basic and Diluted Share	'	'	'	'	'	'	'	'	($6.76)	($0.73)	($1.68)
Income (Loss) from Continuing Operations, Per Outstanding Limited Partnership Unit, Basic	-1.55	-0.82	-4	-0.39	-0.69	-0.46	0.24	0.18	'	'	'
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic and Diluted Share	'	'	'	'	'	'	'	'	($0.24)	$0.03	$0.04
Income (Loss) from Discontinued Operations, Net of Tax, Per Outstanding Limited Partnership Unit, Basic	-0.07	0.02	-0.2	0.01	0.02	0	0.01	0	'	'	'
Earnings Per Share, Basic and Diluted	'	'	'	'	'	'	'	'	($7)	($0.70)	($1.64)
Limited partnersb net income (loss) per unit (basic and diluted)	-1.62	-0.8	-4.2	-0.38	-0.67	-0.46	0.25	0.18	'	'	'
Terminals [Member]	'	'	'	'	'	'	'	'	'	'	'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	($716,000)	$0	$0

LongTerm_Incentive_Plan_Unitba

Long-Term Incentive Plan (Unit-based Awards) (Details)	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, Options, Outstanding	'	'	'
Outstanding at beginning of period	90,938	162,860	205,864
Granted	114,336	38,595	19,414
Forfeited	-18,320	-12,517	0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	-111,425	-98,000	-62,418
Outstanding at end of period	75,529	90,938	162,860
Minimum [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding	'	'	'
Fair value per unit	13.36	14.7	14.7
Maximum [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding	'	'	'
Fair value per unit	25.6	21.4	16.15

Long_Term_Incentive_Plan_Textu

Long Term Incentive Plan (Textual) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Jul. 11, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Equity compensation expense	$2,094,000	$1,783,000	$3,357,000	'
Share-based Compensation Arrangement by Share-based Payment Award, Plan Modification, Incremental Compensation Cost	'	'	1,500,000	'
Long-term incentive plan, increase in available awards	'	'	'	871,750,000
Long term incentive plan available for future grant	855,089,000	920,193	54,827	'
Grants issued under long term incentive plan	25.00%	'	'	'
Total fair value of vested units	'	1,900,000	1,200,000	'
Compensation cost related unvested awards	900,000	1,400,000	2,700,000	'
Weighted average period cost recognized	'1 year 11 months 0 days	'	'	'
Phantom units [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Equity compensation expense	$2,200,000	'	$3,400,000	'

PostEmployment_Benefits_Change

Post-Employment Benefits (Changes in Benefit Obligation) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Change in plan assets	'	'	'
Funded status	$996	$1,080	$966
Defined Benefit Plan, Plan Amendments	126	0	0
Change in Benefit Obligation [Member]	'	'	'
Change in benefit obligation	'	'	'
Obligation, beginning of period	472	466	869
Service cost	5	4	3
Interest cost	15	18	22
Actuarial (gain) loss	29	22	-367
Benefits paid	-57	-38	-61
Benefit obligationm, ending	532	472	466
Change in plan assets	'	'	'
Benefits paid	-57	-38	-61
Change in Plan Assets [Member]	'	'	'
Change in benefit obligation	'	'	'
Benefits paid	-61	-54	-76
Change in plan assets	'	'	'
Fair value of plan assets, beginning of period	1,552	1,432	1,319
Actual return on plan assets	-53	84	99
Employerbs contributions	90	90	90
Benefits paid	-61	-54	-76
Fair value of plan assets, ending	$1,528	$1,552	$1,432

PostEmployment_Benefits_Plan_A

Post-Employment Benefits (Plan Assets Recognized) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Amortization of Net Gains (Losses)	($100)	($100)	$400
OPEB Plan [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Amortization of Net Gains (Losses)	-23	-43	-47
Other assets	$996	$1,080	$966

PostEmployment_Benefits_Net_Pe

Post-Employment Benefits (Net Periodic Benefit Cost) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Pension and Other Postretirement Benefit Plans, Amounts that Will be Amortized from Accumulated Other Comprehensive Income (Loss) in Next Fiscal Year	$100,000	'	'
Cost recognized in Unaudited Condensed Consolidated Statements of Operations	'	'	'
Defined Benefit Plan, Amortization of Net Gains (Losses)	-100,000	-100,000	400,000
Net periodic (benefit) cost	-73,000	-88,000	-82,000
Net loss (gain)	'	64,000	-359,000
OPEB Plan [Member]	'	'	'
Cost recognized in Unaudited Condensed Consolidated Statements of Operations	'	'	'
Service cost	5,000	4,000	3,000
Interest cost	15,000	18,000	22,000
Expected return on plan assets	-70,000	-67,000	-60,000
Defined Benefit Plan, Amortization of Net Gains (Losses)	-23,000	-43,000	-47,000
Net periodic (benefit) cost	-73,000	-88,000	-82,000
Net loss (gain)	-247,000	64,000	-359,000
Total recognized in other comprehensive income	247,000	64,000	-359,000
Total recognized in net periodic benefit cost and other comprehensive income	$174,000	($24,000)	($441,000)

PostEmployment_Benefits_Econom

Post-Employment Benefits (Economic Assumptions) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Effect of one percentage point increase in assumed medical and dental care trend	$0.10	'	'
Effect of one percentage point decrease in assumed medical and dental care trend	$0.10	'	'
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	4.50%	3.00%	3.00%
OPEB Plan [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Discount rate	4.57%	3.42%	3.96%
Expected return on plan assets	4.50%	4.50%	4.50%

PostEmployment_Benefits_Expect

Post-Employment Benefits (Expected Future Benefit Payments) (Details) (OPEB Plan [Member], USD $)	Dec. 31, 2013
OPEB Plan [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Estimated Future Employer Contributions in Current Fiscal Year	$100,000
2013	28,000
2014	29,000
2015	28,000
2016	27,000
2017	27,000
Five years thereafter	$157,000

PostEmployment_Benefits_Weight

Post-Employment Benefits (Weighted Average Asset Allocation) (Details)	Dec. 31, 2013	Dec. 31, 2012		Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'	'		'
Weighted average asset allocation (as a percent)	100.00%	100.00%		100.00%
Fixed Income [Member]	'	'		'
Defined Benefit Plan Disclosure [Line Items]	'	'		'
Weighted average asset allocation (as a percent)	70.10%	72.20%	[1]	72.10%	[1]
Cash and Short Term Assets [Member]	'	'		'
Defined Benefit Plan Disclosure [Line Items]	'	'		'
Weighted average asset allocation (as a percent)	29.90%	27.80%	[2]	27.90%	[2]
[1]	United States government securities, municipal corporate bonds and notes and asset backed securities
[2]	Cash and securities with maturities of one year or less

PostEmployment_Benefits_Detail

Post-Employment Benefits (Details Textual) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Amortization of Net Gains (Losses)	($100)	($100)	$400
OPEB Plan [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Amortization of Net Gains (Losses)	($23)	($43)	($47)

Income_Tax_Details

Income Tax (Details) (USD $)	9 Months Ended	12 Months Ended
	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Deferred taxes [Abstract]	'	'	'	'
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Noncontrolling Interest	'	($31,646,000)	($6,571,000)	($12,030,000)
Current Income Tax Expense (Benefit)	'	0	'	'
Deferred Income Tax Expense (Benefit)	'	495,000	'	'
Effective Income Tax Rate, Continuing Operations	'	0.00%	'	'
Effective income tax rate, continuing operations	35.00%	0.00%	'	'
Operating Loss Carryforwards	'	14,000,000	'	'
Operating Loss Carryforwards	'	5,455,000	'	'
Deferred Tax Assets, Other	'	182,000	'	'
Deferred Tax Assets, Gross	'	5,637,000	'	'
Deferred Tax Liabilities, Property, Plant and Equipment	'	9,022,000	'	'
Deferred Tax Liabilities, Intangible Assets	'	1,364,000	'	'
Deferred Tax Liabilities, Gross	'	10,386,000	'	'
Deferred Tax Liabilities, Net	'	-4,749,000	0	'
Income Tax Reconciliation, Income Tax Expense (Benefit), at Federal Statutory Income Tax Rate	'	10,760,000	'	'
Effective Income Tax Rate Reconciliation, Tax Exempt Income	'	-10,350,000	'	'
Income Tax Reconciliation, Other Adjustments	'	222,000	'	'
Current State and Local Tax Expense (Benefit)	'	71,000	'	'
Income Tax Reconciliation, Prior Year Income Taxes	'	-175,000	'	'
Income Tax Reconciliation, Other Reconciling Items	'	-33,000	'	'
Income Tax Expense (Benefit), Continuing Operations	'	$495,000	$0	$0

Commitments_and_Contingencies_1

Commitments and Contingencies (Contractual Obligations) (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Future Non Cancelable Commitment [Line Items]	'
2012	$959
2013	1,012
2014	8,681
2015	810
2016	584
Thereafter	28,739
Total	40,785
Operating leases and service contract [Member]	'
Future Non Cancelable Commitment [Line Items]	'
2012	959
2013	1,012
2014	814
2015	810
2016	584
Thereafter	1,970
Total	6,149
ARO [Member]	'
Future Non Cancelable Commitment [Line Items]	'
2012	0
2013	0
2014	7,867
2015	0
2016	0
Thereafter	26,769
Total	$34,636

Commitments_and_Contingencies_2

Commitments and Contingencies (Expenses) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Commitments and Contingencies Disclosure [Abstract]	'	'	'
Operating leases	$1,051	$941	$803
Asset retirement obligation	554	32	1,393
Total expenses	($1,605)	($973)	($2,196)

Commitments_and_Contingencies_3

Commitments and Contingencies (Details Textual) (USD $)	1 Months Ended
	Feb. 29, 2012
Commitments and Contingencies Disclosure [Abstract]	'
Civil penalty	$23,010

Related_Party_Transactions_Det

Related- Party Transactions (Details Textual) (USD $)

12 Months Ended

1 Months Ended

12 Months Ended

3 Months Ended

0 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 15, 2013

Oct. 09, 2012

Aug. 31, 2011

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

Dec. 17, 2013

Jul. 10, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

American Infrastructure MLP [Member]

American Infrastructure MLP [Member]

American Infrastructure MLP [Member]

American Midstream, LLC [Member]

American Midstream, LLC [Member]

American Midstream, LLC [Member]

Terminals [Member]

High Point [Member]

High Point [Member]

Revolving Credit Facility [Member]

Blackwater [Member]

Blackwater [Member]

Total Partners Capital

Total Partners Capital

Total Partners Capital

Total Partners Capital

Total Partners Capital

Total Partners Capital

Limited Partner [Member]

Limited Partner [Member]

Limited Partner [Member]

Limited Partner [Member]

Issuance of Preferred Units [Member]

Fourth Amendment [Member]

Blackwater [Member]

Blackwater [Member]

Blackwater [Member]

Blackwater [Member]

Series A [Member]

Repayment of Debt [Member]

Series A [Member]

Related Party Transactions (Textual) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Administrative and operational service expenses

'

'

'

'

'

'

'

'

$14,200,000

$12,500,000

$9,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost of business development activities

'

'

'

'

'

'

'

'

-1,800,000

-400,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Annual fee for Advisory Service

'

'

'

'

'

'

200,000

300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Selling, general and administrative expenses

21,402,000

14,309,000

11,082,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

One time payment of Advisory services

'

'

'

'

'

2,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notes Payable, Related Parties, Current

'

'

'

'

20,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Consideration for Issuance of Preferred Units

'

'

'

'

'

'

'

'

'

'

'

'

15,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Units, Contributed Capital

'

'

'

'

'

'

'

'

'

'

'

'

'

5,142,857

'

'

'

'

'

'

'

'

'

'

'

'

'

Transaction Expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

2,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments on long-term debt

-131,571,000

-59,230,000

-120,670,000

'

'

'

'

'

'

'

'

'

'

'

-12,500,000

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Assets and Liabilities Under Common Control, Assets (Liabilities), Net

'

'

'

61,930,000

'

'

'

'

'

'

'

22,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Cost of Acquired Entity, Purchase Price

6,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

63,900,000

2,500,000

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Distributions

($27,650,000)

$322,000

$864,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$22,251,000

$16,070,000

$43,546,000

$27,650,000

$0

$0

$21,628,000

$15,748,000

$42,682,000

$3,052,000

Units issued in business acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

125,500

'

'

'

'

'

'

'

'

'

'

'

Reporting_Segments_Details

Reporting Segments (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment information	'	'	'	'	'	'	'	'	'	'	'
Revenue, net	'	'	'	'	'	'	'	'	$292,626,000	$194,843,000	$233,169,000
Total revenue	76,108,000	79,536,000	77,608,000	59,402,000	56,663,000	53,401,000	43,322,000	44,857,000	292,654,000	198,243,000	227,719,000
Construction, Operating and Maintenace Expenses	'	'	'	'	'	'	'	'	843,000	3,373,000	-2,998,000
Realized gain (loss) on early termination of commodity derivatives	'	'	'	'	'	'	'	'	0	0	-2,998,000
Unrealized gain (loss) on commodity derivatives	'	'	'	'	'	'	'	'	-1,041,000	992,000	-541,000
Direct operating expenses	'	'	'	'	'	'	'	'	-29,553,000	-16,798,000	-11,419,000
Segment Gross Margin	'	'	'	'	'	'	'	'	76,623,000	48,706,000	43,860,000
Purchases of natural gas, NGLs and condensate	'	'	'	'	'	'	'	'	214,149,000	145,172,000	187,398,000
Selling, general and administrative expenses	'	'	'	'	'	'	'	'	-21,402,000	-14,309,000	-11,082,000
Advisory services agreement termination fee	'	'	'	'	'	'	'	'	0	0	-2,500,000
Allocated Share-based Compensation Expense	'	'	'	'	'	'	'	'	-2,094,000	-1,783,000	-3,357,000
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	-29,999,000	-21,284,000	-20,449,000
Gain (loss) on acquisition of assets	'	'	'	'	'	'	'	'	0	0	565,000
Transaction expenses	'	'	'	'	'	'	'	'	'	'	0
Gain (loss) on involuntary conversion of property, plant and equipment	'	'	'	400,000	'	'	'	'	343,000	-1,021,000	0
Gain on sale of assets, including discontinued operations	'	'	'	'	'	'	'	'	-75,000	128,000	'
Gain on sale of assets, net	'	'	'	'	'	'	'	'	0	123,000	399,000
Impairment of long-lived assets held-for-use	3,000,000	'	15,200,000	100,000	'	'	'	'	18,155,000	0	0
Interest expense	'	'	'	'	'	'	'	'	9,291,000	4,570,000	4,508,000
Income Tax Expense (Benefit), Continuing Operations	'	'	'	'	'	'	'	'	495,000	0	0
Net loss	'	'	'	'	'	'	'	'	-33,406,000	-6,252,000	-11,698,000
Net income attributable to noncontrolling interests	100,000	190,000	188,000	155,000	7,000	249,000	0	0	'	'	'
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	-489,000	91,000	-1,930,000	73,000	225,000	-12,000	75,000	31,000	-2,255,000	319,000	332,000
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	633,000	256,000	'
Net loss attributable to the Partnership	-5,641,000	-2,731,000	-22,114,000	-3,553,000	-6,251,000	-4,275,000	2,327,000	1,691,000	-34,039,000	-6,508,000	-11,698,000
Gathering And Processing [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment information	'	'	'	'	'	'	'	'	'	'	'
Revenue, net	'	'	'	'	'	'	'	'	192,446,000	145,714,000	160,953,000
Construction, Operating and Maintenace Expenses	'	'	'	'	'	'	'	'	689,000	673,000	'
Unrealized gain (loss) on commodity derivatives	'	'	'	'	'	'	'	'	-1,041,000	992,000	-541,000
Direct operating expenses	'	'	'	'	'	'	'	'	-14,214,000	-11,767,000	-6,199,000
Segment Gross Margin	'	'	'	'	'	'	'	'	36,464,000	35,393,000	30,123,000
Purchases of natural gas, NGLs and condensate	'	'	'	'	'	'	'	'	156,334,000	108,656,000	134,369,000
Transmission [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment information	'	'	'	'	'	'	'	'	'	'	'
Revenue, net	'	'	'	'	'	'	'	'	90,377,000	52,529,000	66,766,000
Construction, Operating and Maintenace Expenses	'	'	'	'	'	'	'	'	154,000	2,700,000	0
Unrealized gain (loss) on commodity derivatives	'	'	'	'	'	'	'	'	0	0	0
Direct operating expenses	'	'	'	'	'	'	'	'	-13,259,000	-5,031,000	-5,220,000
Segment Gross Margin	'	'	'	'	'	'	'	'	32,408,000	13,313,000	13,737,000
Purchases of natural gas, NGLs and condensate	'	'	'	'	'	'	'	'	57,815,000	36,516,000	53,029,000
Terminals [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment information	'	'	'	'	'	'	'	'	'	'	'
Revenue, net	'	'	'	'	'	'	'	'	9,831,000	'	'
Construction, Operating and Maintenace Expenses	'	'	'	'	'	'	'	'	0	'	'
Unrealized gain (loss) on commodity derivatives	'	'	'	'	'	'	'	'	0	'	'
Direct operating expenses	'	'	'	'	'	'	'	'	-2,080,000	'	'
Segment Gross Margin	'	'	'	'	'	'	'	'	7,751,000	'	'
Purchases of natural gas, NGLs and condensate	'	'	'	'	'	'	'	'	0	'	'
Gathering and Processing Assets [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment information	'	'	'	'	'	'	'	'	'	'	'
Direct operating expenses	'	'	'	'	'	'	'	'	-27,473,000	'	'
Commodity Contract [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment information	'	'	'	'	'	'	'	'	'	'	'
Realized gain (loss) on early termination of commodity derivatives	'	'	'	'	'	'	'	'	200,000	2,408,000	-4,909,000
Unrealized gain (loss) on commodity derivatives	'	'	'	'	'	'	'	'	-1,495,000	992,000	-541,000
Unrealized Gain (Loss or Write-down) [Member] | Commodity Contract [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment information	'	'	'	'	'	'	'	'	'	'	'
Realized gain (loss) on early termination of commodity derivatives	1,069,000	'	'	'	2,408,000	'	'	'	'	'	-2,998,000
Unrealized gain (loss) on commodity derivatives	'	'	'	'	$992,000	'	'	'	'	'	$0

Reporting_Segments_Reporting_S

Reporting Segments Reporting Segment (Revenue Earned from Customers that Exceed 10%) (Details) (Customer Concentration Risk [Member], Revenue [Member])	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Gathering And Processing [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	100.00%	100.00%	100.00%
Transmission [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	100.00%	100.00%	100.00%
Terminals [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	100.00%	0.00%	0.00%
Customer A [Member] | Gathering And Processing [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	43.00%	40.00%	55.00%
Customer B [Member] | Gathering And Processing [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	19.00%	11.00%	0.00%
Customer B [Member] | Terminals [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	17.00%	0.00%	0.00%
Customer C [Member] | Transmission [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	39.00%	50.00%	57.00%
Customer D [Member] | Gathering And Processing [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	0.00%	12.00%	0.00%
Customer D [Member] | Transmission [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	16.00%	22.00%	22.00%
Customer E [Member] | Transmission [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	0.00%	10.00%	0.00%
Customer H [Member] | Terminals [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	13.00%	0.00%	0.00%
Customer F [Member] | Terminals [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	20.00%	0.00%	0.00%
Customer G [Member] | Terminals [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	16.00%	0.00%	0.00%
Customer Other [Member] | Gathering And Processing [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	38.00%	37.00%	0.00%
Customer Other [Member] | Transmission [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	45.00%	18.00%	21.00%
Customer Other [Member] | Terminals [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Concentration risk, percentage	34.00%	0.00%	0.00%

Reporting_Segments_Details_Tex

Reporting Segments (Details Textual) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Unrealized gain (loss) on commodity derivatives	($1,041)	$992	($541)
Unrealized gain (loss) on derivative contracts	-1,505	992	-849
Construction, Operating and Maintenace Expenses	843	3,373	-2,998
Gathering And Processing [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Unrealized gain (loss) on commodity derivatives	-1,041	992	-541
Construction, Operating and Maintenace Expenses	689	673	'
Transmission [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Unrealized gain (loss) on commodity derivatives	0	0	0
Construction, Operating and Maintenace Expenses	$154	$2,700	$0

Quarterly_Financial_Data_Detai

Quarterly Financial Data (Details) (USD $)	3 Months Ended								12 Months Ended			3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2012
												Recognition of Proceeds Received in Connection with COMA Reimbursable Projects [Member]	Recognition of Proceeds Received in Connection with COMA Reimbursable Projects [Member]	Selling, General and Administrative Expenses [Member]
Quantifying Misstatement in Current Year Financial Statements [Line Items]	'	'	'	'	'	'	'	'	'	'	'	'	'	'
Quantifying Misstatement in Current Year Financial Statements, Amount	'	'	'	'	'	'	'	'	'	'	'	$300,000	'	$100,000
Quantifying Misstatement in Current Year Financial Statements, Quarterly Amount to be Recognized	'	'	'	'	'	'	'	'	'	'	'	'	100,000	'
Total revenue	76,108,000	79,536,000	77,608,000	59,402,000	56,663,000	53,401,000	43,322,000	44,857,000	292,654,000	198,243,000	227,719,000	'	'	'
Gross Profit	23,609,000	21,380,000	19,158,000	12,476,000	11,914,000	12,979,000	11,253,000	12,560,000	'	'	'	'	'	'
Operating Income (Loss)	-2,625,000	-210,000	-17,780,000	-1,740,000	-4,982,000	-2,513,000	3,077,000	2,417,000	-22,355,000	-2,001,000	-7,522,000	'	'	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	-5,052,000	-2,632,000	-19,996,000	-3,471,000	-6,469,000	-4,014,000	2,252,000	1,660,000	-31,151,000	-6,571,000	-12,030,000	'	'	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	-33,406,000	-6,252,000	-11,698,000	'	'	'
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	-489,000	91,000	-1,930,000	73,000	225,000	-12,000	75,000	31,000	-2,255,000	319,000	332,000	'	'	'
Net income attributable to noncontrolling interests	100,000	190,000	188,000	155,000	7,000	249,000	0	0	'	'	'	'	'	'
Net Income (Loss) Attributable to Parent	-5,641,000	-2,731,000	-22,114,000	-3,553,000	-6,251,000	-4,275,000	2,327,000	1,691,000	-34,039,000	-6,508,000	-11,698,000	'	'	'
Net Income (Loss) Allocated to General Partners	-209,000	-221,000	-905,000	-70,000	-124,000	-85,000	46,000	34,000	'	'	'	'	'	'
Net Income (Loss) Allocated to Limited Partners	($5,432,000)	($2,510,000)	($21,209,000)	($3,483,000)	($6,127,000)	($4,190,000)	$2,281,000	$1,657,000	($55,834,000)	($6,378,000)	($11,457,000)	'	'	'
Limited partnersb net income (loss) per unit (basic and diluted)	-1.62	-0.8	-4.2	-0.38	-0.67	-0.46	0.25	0.18	'	'	'	'	'	'
Income (Loss) from Continuing Operations, Per Outstanding Limited Partnership Unit, Basic	-1.55	-0.82	-4	-0.39	-0.69	-0.46	0.24	0.18	'	'	'	'	'	'
Income (Loss) from Discontinued Operations, Net of Tax, Per Outstanding Limited Partnership Unit, Basic	-0.07	0.02	-0.2	0.01	0.02	0	0.01	0	'	'	'	'	'	'

Subsidiary_Guarantors_Narrativ

Subsidiary Guarantors (Narrative) (Details)	6 Months Ended	12 Months Ended
	Jun. 30, 2011	Dec. 31, 2013
		American Midstream Finance Corporation [Member]
Property, Plant and Equipment [Line Items]	'	'
Percentage of agragate limited partner interest	100.00%	100.00%

Subsidiary_Guarantors_Balance_

Subsidiary Guarantors (Balance Sheet) (Details) (USD $)	Dec. 31, 2013	Apr. 15, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Guarantor Obligations [Line Items]	'	'	'	'	'
Noncontrolling Interest, Ownership Percentage by Parent	92.20%	'	'	'	'
Current assets:	'	'	'	'	'
Cash and cash equivalents	$393,000	'	$576,000	$871,000	$63,000
Accounts receivable	6,822,000	'	1,958,000	'	'
Unbilled revenue	22,005,000	'	21,512,000	'	'
Risk management assets	473,000	'	969,000	'	'
Other current assets	7,497,000	'	3,226,000	'	'
Assets Held-for-sale, Current	1,268,000	'	0	'	'
Total current assets	38,458,000	'	28,241,000	'	'
Property, plant and equipment, net	312,510,000	'	223,819,000	'	'
Investment in subsidiaries	0	'	0	'	'
Other assets, net	9,064,000	'	4,636,000	'	'
Assets Held-for-sale, Other, Noncurrent	1,914,000	'	0	'	'
Total assets	382,075,000	'	256,696,000	'	'
Current liabilities:	'	'	'	'	'
Accounts payable	3,261,000	'	5,527,000	'	'
Accrued gas purchases	16,394,000	'	17,034,000	'	'
Accrued expenses and other current liabilities	15,058,000	'	9,619,000	'	'
Total current liabilities	38,290,000	'	32,180,000	'	'
Other liabilities	191,000	'	309,000	'	'
Long-term debt	130,735,000	'	128,285,000	'	'
Total liabilities	208,797,000	'	169,093,000	'	'
Temporary Equity, Carrying Amount, Including Portion Attributable to Noncontrolling Interests	94,811,000	90,000,000	0	'	'
Total partners' capital	73,839,000	'	80,165,000	'	'
Noncontrolling interest	4,628,000	'	7,438,000	'	'
Total equity	78,467,000	'	87,603,000	'	'
Total liabilities and partners' capital	382,075,000	'	256,696,000	'	'
Notes Receivable, Related Parties, Noncurrent	0	'	'	'	'
Goodwill	16,447,000	'	0	'	'
Intangible Assets, Net (Excluding Goodwill)	3,682,000	'	0	'	'
Accrued expenses	5,906,000	'	6,519,000	'	'
Accrued Liabilities and Other Liabilities	15,058,000	'	9,619,000	'	'
Long-term Debt, Current Maturities	2,048,000	'	0	'	'
Derivative Liabilities, Current	423,000	'	0	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	1,106,000	'	0	'	'
Derivative Liabilities, Noncurrent	101,000	'	0	'	'
Asset Retirement Obligation	34,636,000	'	8,319,000	8,093,000	'
Deferred Tax Liabilities, Net	4,749,000	'	0	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	95,000	'	0	'	'
Parent [Member]	'	'	'	'	'
Current assets:	'	'	'	'	'
Cash and cash equivalents	1,000	'	1,000	1,000	'
Accounts receivable	0	'	0	'	'
Unbilled revenue	0	'	0	'	'
Risk management assets	0	'	0	'	'
Other current assets	84,000	'	0	'	'
Assets Held-for-sale, Current	0	'	'	'	'
Total current assets	85,000	'	1,000	'	'
Property, plant and equipment, net	0	'	0	'	'
Investment in subsidiaries	142,758,000	'	80,164,000	'	'
Other assets, net	0	'	0	'	'
Assets Held-for-sale, Other, Noncurrent	0	'	'	'	'
Total assets	170,158,000	'	80,165,000	'	'
Current liabilities:	'	'	'	'	'
Accounts payable	30,000	'	0	'	'
Accrued gas purchases	0	'	0	'	'
Accrued expenses and other current liabilities	'	'	0	'	'
Total current liabilities	1,508,000	'	0	'	'
Other liabilities	0	'	0	'	'
Long-term debt	0	'	0	'	'
Total liabilities	1,508,000	'	0	'	'
Temporary Equity, Carrying Amount, Including Portion Attributable to Noncontrolling Interests	94,811,000	'	'	'	'
Total partners' capital	73,839,000	'	80,165,000	'	'
Noncontrolling interest	0	'	0	'	'
Total equity	73,839,000	'	80,165,000	'	'
Total liabilities and partners' capital	170,158,000	'	80,165,000	'	'
Notes Receivable, Related Parties, Noncurrent	27,315,000	'	'	'	'
Goodwill	0	'	'	'	'
Intangible Assets, Net (Excluding Goodwill)	0	'	'	'	'
Accrued expenses	1,478,000	'	'	'	'
Long-term Debt, Current Maturities	0	'	'	'	'
Derivative Liabilities, Current	0	'	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	0	'	'	'	'
Derivative Liabilities, Noncurrent	0	'	'	'	'
Asset Retirement Obligation	0	'	0	'	'
Deferred Tax Liabilities, Net	0	'	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	0	'	'	'	'
Guarantor Subsidiaries [Member]	'	'	'	'	'
Current assets:	'	'	'	'	'
Cash and cash equivalents	392,000	'	575,000	870,000	'
Accounts receivable	4,461,000	'	1,612,000	'	'
Unbilled revenue	17,325,000	'	18,102,000	'	'
Risk management assets	473,000	'	969,000	'	'
Other current assets	6,942,000	'	2,967,000	'	'
Assets Held-for-sale, Current	1,268,000	'	'	'	'
Total current assets	30,861,000	'	24,225,000	'	'
Property, plant and equipment, net	254,465,000	'	165,001,000	'	'
Investment in subsidiaries	57,750,000	'	51,613,000	'	'
Other assets, net	8,321,000	'	4,636,000	'	'
Assets Held-for-sale, Other, Noncurrent	1,914,000	'	'	'	'
Total assets	373,440,000	'	245,475,000	'	'
Current liabilities:	'	'	'	'	'
Accounts payable	2,902,000	'	5,100,000	'	'
Accrued gas purchases	13,290,000	'	14,606,000	'	'
Accrued expenses and other current liabilities	'	'	9,150,000	'	'
Total current liabilities	33,332,000	'	28,856,000	'	'
Other liabilities	191,000	'	309,000	'	'
Long-term debt	158,050,000	'	128,285,000	'	'
Total liabilities	230,682,000	'	165,311,000	'	'
Temporary Equity, Carrying Amount, Including Portion Attributable to Noncontrolling Interests	0	'	'	'	'
Total partners' capital	142,758,000	'	80,164,000	'	'
Noncontrolling interest	0	'	0	'	'
Total equity	142,758,000	'	80,164,000	'	'
Total liabilities and partners' capital	373,440,000	'	245,475,000	'	'
Notes Receivable, Related Parties, Noncurrent	0	'	'	'	'
Goodwill	16,447,000	'	'	'	'
Intangible Assets, Net (Excluding Goodwill)	3,682,000	'	'	'	'
Accrued expenses	13,563,000	'	'	'	'
Long-term Debt, Current Maturities	2,048,000	'	'	'	'
Derivative Liabilities, Current	423,000	'	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	1,106,000	'	'	'	'
Derivative Liabilities, Noncurrent	101,000	'	'	'	'
Asset Retirement Obligation	34,164,000	'	7,861,000	'	'
Deferred Tax Liabilities, Net	4,749,000	'	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	95,000	'	'	'	'
Non-Guarantor Subsidiaries [Member]	'	'	'	'	'
Current assets:	'	'	'	'	'
Cash and cash equivalents	0	'	0	0	'
Accounts receivable	2,361,000	'	346,000	'	'
Unbilled revenue	4,680,000	'	3,410,000	'	'
Risk management assets	0	'	0	'	'
Other current assets	555,000	'	259,000	'	'
Assets Held-for-sale, Current	0	'	'	'	'
Total current assets	7,596,000	'	4,015,000	'	'
Property, plant and equipment, net	58,045,000	'	58,818,000	'	'
Investment in subsidiaries	0	'	0	'	'
Other assets, net	743,000	'	0	'	'
Assets Held-for-sale, Other, Noncurrent	0	'	'	'	'
Total assets	66,384,000	'	62,833,000	'	'
Current liabilities:	'	'	'	'	'
Accounts payable	329,000	'	427,000	'	'
Accrued gas purchases	3,104,000	'	2,428,000	'	'
Accrued expenses and other current liabilities	'	'	469,000	'	'
Total current liabilities	3,534,000	'	3,324,000	'	'
Other liabilities	0	'	0	'	'
Long-term debt	0	'	0	'	'
Total liabilities	4,006,000	'	3,782,000	'	'
Temporary Equity, Carrying Amount, Including Portion Attributable to Noncontrolling Interests	0	'	'	'	'
Total partners' capital	57,750,000	'	51,613,000	'	'
Noncontrolling interest	4,628,000	'	7,438,000	'	'
Total equity	62,378,000	'	59,051,000	'	'
Total liabilities and partners' capital	66,384,000	'	62,833,000	'	'
Notes Receivable, Related Parties, Noncurrent	0	'	'	'	'
Goodwill	0	'	'	'	'
Intangible Assets, Net (Excluding Goodwill)	0	'	'	'	'
Accrued expenses	101,000	'	'	'	'
Long-term Debt, Current Maturities	0	'	'	'	'
Derivative Liabilities, Current	0	'	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	0	'	'	'	'
Derivative Liabilities, Noncurrent	0	'	'	'	'
Asset Retirement Obligation	472,000	'	458,000	'	'
Deferred Tax Liabilities, Net	0	'	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	0	'	'	'	'
Consolidation Adjustments [Member]	'	'	'	'	'
Current assets:	'	'	'	'	'
Cash and cash equivalents	0	'	0	0	'
Accounts receivable	0	'	0	'	'
Unbilled revenue	0	'	0	'	'
Risk management assets	0	'	0	'	'
Other current assets	-84,000	'	0	'	'
Assets Held-for-sale, Current	0	'	'	'	'
Total current assets	-84,000	'	0	'	'
Property, plant and equipment, net	0	'	0	'	'
Investment in subsidiaries	-200,508,000	'	-131,777,000	'	'
Other assets, net	0	'	0	'	'
Assets Held-for-sale, Other, Noncurrent	0	'	'	'	'
Total assets	-227,907,000	'	-131,777,000	'	'
Current liabilities:	'	'	'	'	'
Accounts payable	0	'	0	'	'
Accrued gas purchases	0	'	0	'	'
Accrued expenses and other current liabilities	'	'	0	'	'
Total current liabilities	-84,000	'	0	'	'
Other liabilities	0	'	0	'	'
Long-term debt	-27,315,000	'	0	'	'
Total liabilities	-27,399,000	'	0	'	'
Temporary Equity, Carrying Amount, Including Portion Attributable to Noncontrolling Interests	0	'	'	'	'
Total partners' capital	-200,508,000	'	-131,777,000	'	'
Noncontrolling interest	0	'	0	'	'
Total equity	-200,508,000	'	-131,777,000	'	'
Total liabilities and partners' capital	-227,907,000	'	-131,777,000	'	'
Notes Receivable, Related Parties, Noncurrent	-27,315,000	'	'	'	'
Goodwill	0	'	'	'	'
Intangible Assets, Net (Excluding Goodwill)	0	'	'	'	'
Accrued expenses	-84,000	'	'	'	'
Long-term Debt, Current Maturities	0	'	'	'	'
Derivative Liabilities, Current	0	'	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	0	'	'	'	'
Derivative Liabilities, Noncurrent	0	'	'	'	'
Asset Retirement Obligation	0	'	0	'	'
Deferred Tax Liabilities, Net	0	'	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	$0	'	'	'	'

Subsidiary_Guarantors_Statemen

Subsidiary Guarantors (Statement of Operations) (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Guarantor Obligations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	($489,000)	$91,000	($1,930,000)	$73,000	$225,000	($12,000)	$75,000	$31,000	($2,255,000)	$319,000	$332,000
Revenues:	'	'	'	'	'	'	'	'	'	'	'
Revenue	'	'	'	'	'	'	'	'	292,626,000	194,843,000	233,169,000
Unrealized gain (loss) on commodity derivatives	'	'	'	'	'	'	'	'	28,000	3,400,000	-2,452,000
Total revenue	76,108,000	79,536,000	77,608,000	59,402,000	56,663,000	53,401,000	43,322,000	44,857,000	292,654,000	198,243,000	227,719,000
Operating Expenses:	'	'	'	'	'	'	'	'	'	'	'
Purchases of natural gas, NGLs and condensate	'	'	'	'	'	'	'	'	214,149,000	145,172,000	187,398,000
Direct operating expenses	'	'	'	'	'	'	'	'	29,553,000	16,798,000	11,419,000
Selling, general and administrative expenses	'	'	'	'	'	'	'	'	21,402,000	14,309,000	11,082,000
Equity compensation expense	'	'	'	'	'	'	'	'	2,094,000	1,783,000	3,357,000
Depreciation and accretion expense	'	'	'	'	'	'	'	'	25,900,000	21,400,000	'
Gain (loss) on involuntary conversion of property, plant and equipment	'	'	'	400,000	'	'	'	'	343,000	-1,021,000	0
Gain on sale of assets, net	'	'	'	'	'	'	'	'	0	123,000	399,000
Gain on sale of assets, including discontinued operations	'	'	'	'	'	'	'	'	-75,000	128,000	'
Impairment of Long-Lived Assets Held-for-use	-3,000,000	'	-15,200,000	-100,000	'	'	'	'	-18,155,000	0	0
Operating (loss) income	-2,625,000	-210,000	-17,780,000	-1,740,000	-4,982,000	-2,513,000	3,077,000	2,417,000	-22,355,000	-2,001,000	-7,522,000
Other Income (expenses):	'	'	'	'	'	'	'	'	'	'	'
Earnings from consolidated affiliates	'	'	'	'	'	'	'	'	0	0	'
Interest expense	'	'	'	'	'	'	'	'	9,291,000	4,570,000	4,508,000
Net loss	'	'	'	'	'	'	'	'	-33,406,000	-6,252,000	-11,698,000
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	633,000	256,000	'
Net income attributable to noncontrolling interests	100,000	190,000	188,000	155,000	7,000	249,000	0	0	'	'	'
Net loss attributable to the Partnership	-5,641,000	-2,731,000	-22,114,000	-3,553,000	-6,251,000	-4,275,000	2,327,000	1,691,000	-34,039,000	-6,508,000	-11,698,000
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	-5,052,000	-2,632,000	-19,996,000	-3,471,000	-6,469,000	-4,014,000	2,252,000	1,660,000	-31,151,000	-6,571,000	-12,030,000
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	29,999,000	21,284,000	20,449,000
Total operating expenses	'	'	'	'	'	'	'	'	297,197,000	199,346,000	236,205,000
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Noncontrolling Interest	'	'	'	'	'	'	'	'	-31,646,000	-6,571,000	-12,030,000
Income Tax Expense (Benefit), Continuing Operations	'	'	'	'	'	'	'	'	495,000	0	0
Unrealized (loss) gain on post retirement benefit plan assets and liabilities	'	'	'	'	'	'	'	'	'	-64,000	359,000
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	-33,653,000	-6,316,000	-11,339,000
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	'	'	'	'	'	'	'	'	-34,286,000	-6,572,000	-11,339,000
Parent [Member]	'	'	'	'	'	'	'	'	'	'	'
Guarantor Obligations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	'	'	'	'	'	'	'	'	0	0	'
Revenues:	'	'	'	'	'	'	'	'	'	'	'
Revenue	'	'	'	'	'	'	'	'	0	0	'
Unrealized gain (loss) on commodity derivatives	'	'	'	'	'	'	'	'	0	0	'
Total revenue	'	'	'	'	'	'	'	'	0	0	'
Operating Expenses:	'	'	'	'	'	'	'	'	'	'	'
Purchases of natural gas, NGLs and condensate	'	'	'	'	'	'	'	'	0	0	'
Direct operating expenses	'	'	'	'	'	'	'	'	0	0	'
Selling, general and administrative expenses	'	'	'	'	'	'	'	'	0	0	'
Equity compensation expense	'	'	'	'	'	'	'	'	0	0	'
Depreciation and accretion expense	'	'	'	'	'	'	'	'	0	0	'
Gain (loss) on involuntary conversion of property, plant and equipment	'	'	'	'	'	'	'	'	0	0	'
Gain on sale of assets, net	'	'	'	'	'	'	'	'	'	'	'
Impairment of Long-Lived Assets Held-for-use	'	'	'	'	'	'	'	'	0	'	'
Operating (loss) income	'	'	'	'	'	'	'	'	0	0	'
Other Income (expenses):	'	'	'	'	'	'	'	'	'	'	'
Earnings from consolidated affiliates	'	'	'	'	'	'	'	'	-34,123,000	-6,508,000	'
Interest expense	'	'	'	'	'	'	'	'	84,000	0	'
Net loss	'	'	'	'	'	'	'	'	-34,039,000	-6,508,000	'
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	0	0	'
Net loss attributable to the Partnership	'	'	'	'	'	'	'	'	-34,039,000	-6,508,000	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	-34,039,000	-6,508,000	'
Total operating expenses	'	'	'	'	'	'	'	'	0	0	'
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Noncontrolling Interest	'	'	'	'	'	'	'	'	-34,039,000	'	'
Income Tax Expense (Benefit), Continuing Operations	'	'	'	'	'	'	'	'	0	'	'
Unrealized (loss) gain on post retirement benefit plan assets and liabilities	'	'	'	'	'	'	'	'	-247,000	-64,000	'
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	-34,286,000	-6,572,000	'
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	'	'	'	'	'	'	'	'	-34,286,000	-6,572,000	'
Guarantor Subsidiaries [Member]	'	'	'	'	'	'	'	'	'	'	'
Guarantor Obligations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	'	'	'	'	'	'	'	'	-2,255,000	319,000	'
Revenues:	'	'	'	'	'	'	'	'	'	'	'
Revenue	'	'	'	'	'	'	'	'	242,395,000	170,569,000	'
Unrealized gain (loss) on commodity derivatives	'	'	'	'	'	'	'	'	-369,000	3,400,000	'
Total revenue	'	'	'	'	'	'	'	'	242,026,000	173,969,000	'
Operating Expenses:	'	'	'	'	'	'	'	'	'	'	'
Purchases of natural gas, NGLs and condensate	'	'	'	'	'	'	'	'	175,551,000	126,649,000	'
Direct operating expenses	'	'	'	'	'	'	'	'	25,180,000	13,895,000	'
Selling, general and administrative expenses	'	'	'	'	'	'	'	'	21,402,000	14,309,000	'
Equity compensation expense	'	'	'	'	'	'	'	'	2,094,000	1,783,000	'
Depreciation and accretion expense	'	'	'	'	'	'	'	'	28,338,000	20,474,000	'
Gain (loss) on involuntary conversion of property, plant and equipment	'	'	'	'	'	'	'	'	343,000	-1,021,000	'
Gain on sale of assets, net	'	'	'	'	'	'	'	'	'	123,000	'
Impairment of Long-Lived Assets Held-for-use	'	'	'	'	'	'	'	'	-18,155,000	'	'
Operating (loss) income	'	'	'	'	'	'	'	'	-28,351,000	-4,039,000	'
Other Income (expenses):	'	'	'	'	'	'	'	'	'	'	'
Earnings from consolidated affiliates	'	'	'	'	'	'	'	'	5,363,000	1,782,000	'
Interest expense	'	'	'	'	'	'	'	'	9,375,000	4,570,000	'
Net loss	'	'	'	'	'	'	'	'	-34,123,000	-6,508,000	'
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	0	0	'
Net loss attributable to the Partnership	'	'	'	'	'	'	'	'	-34,123,000	-6,508,000	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	-31,868,000	-6,827,000	'
Total operating expenses	'	'	'	'	'	'	'	'	252,565,000	177,110,000	'
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Noncontrolling Interest	'	'	'	'	'	'	'	'	-32,363,000	'	'
Income Tax Expense (Benefit), Continuing Operations	'	'	'	'	'	'	'	'	495,000	'	'
Unrealized (loss) gain on post retirement benefit plan assets and liabilities	'	'	'	'	'	'	'	'	-247,000	-64,000	'
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	-34,370,000	-6,572,000	'
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	'	'	'	'	'	'	'	'	-34,370,000	-6,572,000	'
Non-Guarantor Subsidiaries [Member]	'	'	'	'	'	'	'	'	'	'	'
Guarantor Obligations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	'	'	'	'	'	'	'	'	0	0	'
Revenues:	'	'	'	'	'	'	'	'	'	'	'
Revenue	'	'	'	'	'	'	'	'	'	25,441,000	'
Unrealized gain (loss) on commodity derivatives	'	'	'	'	'	'	'	'	397,000	0	'
Total revenue	'	'	'	'	'	'	'	'	56,477,000	25,441,000	'
Operating Expenses:	'	'	'	'	'	'	'	'	'	'	'
Purchases of natural gas, NGLs and condensate	'	'	'	'	'	'	'	'	44,447,000	19,690,000	'
Direct operating expenses	'	'	'	'	'	'	'	'	4,373,000	2,903,000	'
Selling, general and administrative expenses	'	'	'	'	'	'	'	'	0	0	'
Equity compensation expense	'	'	'	'	'	'	'	'	0	0	'
Depreciation and accretion expense	'	'	'	'	'	'	'	'	1,661,000	810,000	'
Gain (loss) on involuntary conversion of property, plant and equipment	'	'	'	'	'	'	'	'	0	0	'
Gain on sale of assets, net	'	'	'	'	'	'	'	'	'	'	'
Impairment of Long-Lived Assets Held-for-use	'	'	'	'	'	'	'	'	0	'	'
Operating (loss) income	'	'	'	'	'	'	'	'	5,996,000	2,038,000	'
Other Income (expenses):	'	'	'	'	'	'	'	'	'	'	'
Earnings from consolidated affiliates	'	'	'	'	'	'	'	'	0	0	'
Interest expense	'	'	'	'	'	'	'	'	0	0	'
Net loss	'	'	'	'	'	'	'	'	5,996,000	2,038,000	'
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	633,000	256,000	'
Net loss attributable to the Partnership	'	'	'	'	'	'	'	'	'	1,782,000	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	5,996,000	2,038,000	'
Total operating expenses	'	'	'	'	'	'	'	'	50,481,000	23,403,000	'
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Noncontrolling Interest	'	'	'	'	'	'	'	'	5,996,000	'	'
Income Tax Expense (Benefit), Continuing Operations	'	'	'	'	'	'	'	'	0	'	'
Unrealized (loss) gain on post retirement benefit plan assets and liabilities	'	'	'	'	'	'	'	'	0	0	'
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	5,996,000	2,038,000	'
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	'	'	'	'	'	'	'	'	5,363,000	1,782,000	'
Consolidation Adjustments [Member]	'	'	'	'	'	'	'	'	'	'	'
Guarantor Obligations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	'	'	'	'	'	'	'	'	0	0	'
Revenues:	'	'	'	'	'	'	'	'	'	'	'
Revenue	'	'	'	'	'	'	'	'	-5,849,000	-1,167,000	'
Unrealized gain (loss) on commodity derivatives	'	'	'	'	'	'	'	'	0	0	'
Total revenue	'	'	'	'	'	'	'	'	-5,849,000	-1,167,000	'
Operating Expenses:	'	'	'	'	'	'	'	'	'	'	'
Purchases of natural gas, NGLs and condensate	'	'	'	'	'	'	'	'	-5,849,000	-1,167,000	'
Direct operating expenses	'	'	'	'	'	'	'	'	0	0	'
Selling, general and administrative expenses	'	'	'	'	'	'	'	'	0	0	'
Equity compensation expense	'	'	'	'	'	'	'	'	0	0	'
Depreciation and accretion expense	'	'	'	'	'	'	'	'	0	0	'
Gain (loss) on involuntary conversion of property, plant and equipment	'	'	'	'	'	'	'	'	0	0	'
Gain on sale of assets, net	'	'	'	'	'	'	'	'	'	'	'
Impairment of Long-Lived Assets Held-for-use	'	'	'	'	'	'	'	'	0	'	'
Operating (loss) income	'	'	'	'	'	'	'	'	0	0	'
Other Income (expenses):	'	'	'	'	'	'	'	'	'	'	'
Earnings from consolidated affiliates	'	'	'	'	'	'	'	'	28,760,000	4,726,000	'
Interest expense	'	'	'	'	'	'	'	'	0	0	'
Net loss	'	'	'	'	'	'	'	'	28,760,000	4,726,000	'
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	0	0	'
Net loss attributable to the Partnership	'	'	'	'	'	'	'	'	28,760,000	4,726,000	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	28,760,000	4,726,000	'
Total operating expenses	'	'	'	'	'	'	'	'	-5,849,000	-1,167,000	'
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Noncontrolling Interest	'	'	'	'	'	'	'	'	28,760,000	'	'
Income Tax Expense (Benefit), Continuing Operations	'	'	'	'	'	'	'	'	0	'	'
Unrealized (loss) gain on post retirement benefit plan assets and liabilities	'	'	'	'	'	'	'	'	247,000	64,000	'
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	29,007,000	4,790,000	'
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	'	'	'	'	'	'	'	'	29,007,000	4,790,000	'
Total Partners Capital	'	'	'	'	'	'	'	'	'	'	'
Other Income (expenses):	'	'	'	'	'	'	'	'	'	'	'
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	633,000	'	'
Net loss attributable to the Partnership	'	'	'	'	'	'	'	'	-34,039,000	-6,508,000	-11,698,000
Unrealized (loss) gain on post retirement benefit plan assets and liabilities	'	'	'	'	'	'	'	'	-247,000	'	'
Noncontrolling Interest	'	'	'	'	'	'	'	'	'	'	'
Other Income (expenses):	'	'	'	'	'	'	'	'	'	'	'
Net loss	'	'	'	'	'	'	'	'	633,000	'	'
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	'	'	0
Chatom processing, gathering and fractionation plant [Member] | Non-Guarantor Subsidiaries [Member]	'	'	'	'	'	'	'	'	'	'	'
Revenues:	'	'	'	'	'	'	'	'	'	'	'
Revenue	'	'	'	'	'	'	'	'	56,080,000	246,342,000	'
Other Income (expenses):	'	'	'	'	'	'	'	'	'	'	'
Net loss attributable to the Partnership	'	'	'	'	'	'	'	'	$5,363,000	($4,319,000)	'

Subsidiary_Guarantors_Statemen1

Subsidiary Guarantors (Statement of Cash Flows) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Condensed Financial Statements, Captions [Line Items]	'	'	'
Net Cash Provided by (Used in) Operating Activities	$17,223,000	$18,348,000	$10,432,000
Payments to Acquire Businesses, Net of Cash Acquired	'	-51,377,000	'
Payments to Acquire Property, Plant, and Equipment	-27,196,000	-11,705,000	-6,369,000
Proceeds from disposals of property, plant and equipment	500,000	128,000	125,000
Cash flows from investing activities	482,000	527,000	0
Increase (Decrease) in Restricted Cash	-2,000,000	0	0
Proceeds from Contributions from Affiliates, Investing Activities	0	0	'
Payments of Distributions to Affiliates, Investing Activities	0	0	'
Cost of acquisitions, net of cash acquired	-28,214,000	-62,427,000	-41,744,000
Proceeds from Contributions from Affiliates	0	0	'
Payments of Distributions to Affiliates	0	0	'
Partners' Capital Account, Public Sale of Units Net of Offering Costs	54,853,000	0	69,085,000
Proceeds from disposal of property, plant and equipment	13,075,000	13,000	0
Distribution Made to Member or Limited Partner, Cash Distributions Paid	-16,120,000	-16,070,000	-43,546,000
Proceeds from Issuance of Convertible Preferred Units	14,393,000	0	0
Partners' Capital Account, Distributions	-27,650,000	322,000	864,000
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	-752,000	0	0
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	-661,000	-225,000	0
Unit holder contributions	-630,000	-385,000	-215,000
Payments of Debt Issuance Costs	-2,113,000	-1,564,000	-2,489,000
Repayments of Notes Payable	2,640,000	0	615,000
Repayments of Related Party Debt	-20,000,000	0	0
Proceeds From Loans Payable	3,795,000	0	0
Repayments of Other Debt	-34,730,000	0	0
Proceeds from Other Debt	27,546,000	0	0
Payments on long-term debt	-131,571,000	-59,230,000	-120,670,000
Proceeds from Issuance of Long-term Debt	134,021,000	121,245,000	130,570,000
Deferred debt issuance costs	10,816,000	43,784,000	32,120,000
Cash and Cash Equivalents, Period Increase (Decrease)	-175,000	-295,000	808,000
Cash and cash equivalents	393,000	576,000	871,000
Cash and cash equivalents, including discontinued operations	401,000	576,000	'
Interest Paid	6,416,000	3,185,000	3,349,000
Capital Expenditures Incurred but Not yet Paid	-5,181,000	-6,968,000	-75,000
Partners' Capital Account, Distributions to Existing Interest	15,612,000	0	0
Accrued Unitholder Distributions	4,811,000	0	0
Other Current Assets Includes Receivables For Construction in Progress	0	141,000	872,000
Parent [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Net Cash Provided by (Used in) Operating Activities	0	0	'
Payments to Acquire Businesses, Net of Cash Acquired	'	0	'
Payments to Acquire Property, Plant, and Equipment	0	0	'
Proceeds from disposals of property, plant and equipment	0	0	'
Cash flows from investing activities	0	0	'
Increase (Decrease) in Restricted Cash	0	'	'
Proceeds from Contributions from Affiliates, Investing Activities	43,770,000	16,070,000	'
Payments of Distributions to Affiliates, Investing Activities	-82,321,000	-13,000	'
Cost of acquisitions, net of cash acquired	-38,551,000	16,057,000	'
Proceeds from Contributions from Affiliates	0	0	'
Payments of Distributions to Affiliates	0	0	'
Partners' Capital Account, Public Sale of Units Net of Offering Costs	54,853,000	'	'
Proceeds from disposal of property, plant and equipment	13,075,000	13,000	'
Distribution Made to Member or Limited Partner, Cash Distributions Paid	-16,120,000	-16,070,000	'
Proceeds from Issuance of Convertible Preferred Units	14,393,000	'	'
Partners' Capital Account, Distributions	-27,650,000	'	'
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	0	'	'
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	0	0	'
Unit holder contributions	0	0	'
Payments of Debt Issuance Costs	0	0	'
Repayments of Notes Payable	0	'	'
Repayments of Related Party Debt	0	'	'
Proceeds From Loans Payable	0	'	'
Repayments of Other Debt	0	'	'
Proceeds from Other Debt	0	'	'
Payments on long-term debt	0	0	'
Proceeds from Issuance of Long-term Debt	0	0	'
Deferred debt issuance costs	38,551,000	-16,057,000	'
Cash and Cash Equivalents, Period Increase (Decrease)	0	0	'
Cash and cash equivalents	1,000	1,000	1,000
Cash and cash equivalents, including discontinued operations	1,000	1,000	'
Interest Paid	0	0	'
Capital Expenditures Incurred but Not yet Paid	0	0	'
Partners' Capital Account, Distributions to Existing Interest	15,612,000	'	'
Accrued Unitholder Distributions	4,811,000	'	'
Other Current Assets Includes Receivables For Construction in Progress	'	0	'
Guarantor Subsidiaries [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Quantifying Misstatement in Current Year Financial Statements, Amount	'	100,000	'
Net Cash Provided by (Used in) Operating Activities	13,681,000	16,310,000	'
Payments to Acquire Businesses, Net of Cash Acquired	'	-51,377,000	'
Payments to Acquire Property, Plant, and Equipment	-26,322,000	-10,870,000	'
Proceeds from disposals of property, plant and equipment	500,000	128,000	'
Cash flows from investing activities	482,000	527,000	'
Increase (Decrease) in Restricted Cash	-2,000,000	'	'
Proceeds from Contributions from Affiliates, Investing Activities	0	0	'
Payments of Distributions to Affiliates, Investing Activities	0	0	'
Cost of acquisitions, net of cash acquired	-27,340,000	-61,592,000	'
Proceeds from Contributions from Affiliates	82,321,000	13,000	'
Payments of Distributions to Affiliates	-42,515,000	-15,092,000	'
Partners' Capital Account, Public Sale of Units Net of Offering Costs	0	'	'
Proceeds from disposal of property, plant and equipment	0	0	'
Distribution Made to Member or Limited Partner, Cash Distributions Paid	0	0	'
Proceeds from Issuance of Convertible Preferred Units	0	'	'
Partners' Capital Account, Distributions	0	'	'
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	0	'	'
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	0	0	'
Unit holder contributions	-630,000	-385,000	'
Payments of Debt Issuance Costs	-2,113,000	-1,564,000	'
Repayments of Notes Payable	2,640,000	'	'
Repayments of Related Party Debt	-20,000,000	'	'
Proceeds From Loans Payable	3,795,000	'	'
Repayments of Other Debt	-34,730,000	'	'
Proceeds from Other Debt	27,546,000	'	'
Payments on long-term debt	-131,571,000	-59,230,000	'
Proceeds from Issuance of Long-term Debt	134,021,000	121,245,000	'
Deferred debt issuance costs	13,484,000	44,987,000	'
Cash and Cash Equivalents, Period Increase (Decrease)	-175,000	-295,000	'
Cash and cash equivalents	392,000	575,000	870,000
Cash and cash equivalents, including discontinued operations	400,000	575,000	'
Interest Paid	6,416,000	3,185,000	'
Capital Expenditures Incurred but Not yet Paid	-5,181,000	-6,968,000	'
Noncash or Part Noncash Acquisition, Net Nonmonetary Assets Acquired (Liabilities Assumed)	0	'	'
Partners' Capital Account, Distributions to Existing Interest	0	'	'
Accrued Unitholder Distributions	0	'	'
Other Current Assets Includes Receivables For Construction in Progress	'	141,000	'
Non-Guarantor Subsidiaries [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Net Cash Provided by (Used in) Operating Activities	3,542,000	2,038,000	'
Payments to Acquire Businesses, Net of Cash Acquired	'	0	'
Payments to Acquire Property, Plant, and Equipment	-874,000	-835,000	'
Proceeds from disposals of property, plant and equipment	0	0	'
Cash flows from investing activities	0	0	'
Increase (Decrease) in Restricted Cash	0	'	'
Proceeds from Contributions from Affiliates, Investing Activities	0	0	'
Payments of Distributions to Affiliates, Investing Activities	0	0	'
Cost of acquisitions, net of cash acquired	-874,000	-835,000	'
Proceeds from Contributions from Affiliates	0	0	'
Payments of Distributions to Affiliates	-1,255,000	-978,000	'
Partners' Capital Account, Public Sale of Units Net of Offering Costs	0	'	'
Proceeds from disposal of property, plant and equipment	0	0	'
Distribution Made to Member or Limited Partner, Cash Distributions Paid	0	0	'
Proceeds from Issuance of Convertible Preferred Units	0	'	'
Partners' Capital Account, Distributions	0	'	'
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	-752,000	'	'
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	-661,000	-225,000	'
Unit holder contributions	0	0	'
Payments of Debt Issuance Costs	0	0	'
Repayments of Notes Payable	0	'	'
Repayments of Related Party Debt	0	'	'
Proceeds From Loans Payable	0	'	'
Repayments of Other Debt	0	'	'
Proceeds from Other Debt	0	'	'
Payments on long-term debt	0	0	'
Proceeds from Issuance of Long-term Debt	0	0	'
Deferred debt issuance costs	-2,668,000	-1,203,000	'
Cash and Cash Equivalents, Period Increase (Decrease)	0	0	'
Cash and cash equivalents	0	0	0
Cash and cash equivalents, including discontinued operations	0	0	'
Interest Paid	0	0	'
Capital Expenditures Incurred but Not yet Paid	0	0	'
Noncash or Part Noncash Acquisition, Net Nonmonetary Assets Acquired (Liabilities Assumed)	0	'	'
Partners' Capital Account, Distributions to Existing Interest	0	'	'
Accrued Unitholder Distributions	0	'	'
Other Current Assets Includes Receivables For Construction in Progress	'	0	'
Consolidation Adjustments [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Net Cash Provided by (Used in) Operating Activities	0	0	'
Payments to Acquire Businesses, Net of Cash Acquired	'	0	'
Payments to Acquire Property, Plant, and Equipment	0	0	'
Proceeds from disposals of property, plant and equipment	0	0	'
Cash flows from investing activities	0	0	'
Increase (Decrease) in Restricted Cash	0	'	'
Proceeds from Contributions from Affiliates, Investing Activities	-43,770,000	-16,070,000	'
Payments of Distributions to Affiliates, Investing Activities	82,321,000	-13,000	'
Cost of acquisitions, net of cash acquired	38,551,000	-16,057,000	'
Proceeds from Contributions from Affiliates	-82,321,000	-13,000	'
Payments of Distributions to Affiliates	43,770,000	16,070,000	'
Partners' Capital Account, Public Sale of Units Net of Offering Costs	0	'	'
Proceeds from disposal of property, plant and equipment	0	0	'
Distribution Made to Member or Limited Partner, Cash Distributions Paid	0	0	'
Proceeds from Issuance of Convertible Preferred Units	0	'	'
Partners' Capital Account, Distributions	0	'	'
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	0	'	'
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	0	0	'
Unit holder contributions	0	0	'
Payments of Debt Issuance Costs	0	0	'
Repayments of Notes Payable	0	'	'
Repayments of Related Party Debt	0	'	'
Proceeds From Loans Payable	0	'	'
Repayments of Other Debt	0	'	'
Proceeds from Other Debt	0	'	'
Payments on long-term debt	0	0	'
Proceeds from Issuance of Long-term Debt	0	0	'
Deferred debt issuance costs	-38,551,000	16,057,000	'
Cash and Cash Equivalents, Period Increase (Decrease)	0	0	'
Cash and cash equivalents	0	0	0
Cash and cash equivalents, including discontinued operations	0	0	'
Interest Paid	0	0	'
Capital Expenditures Incurred but Not yet Paid	0	0	'
Noncash or Part Noncash Acquisition, Net Nonmonetary Assets Acquired (Liabilities Assumed)	0	'	'
Partners' Capital Account, Distributions to Existing Interest	0	'	'
Accrued Unitholder Distributions	0	'	'
Other Current Assets Includes Receivables For Construction in Progress	'	0	'
ArcLight [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Noncash or Part Noncash Acquisition, Net Nonmonetary Assets Acquired (Liabilities Assumed)	59,995,000	0	0
Blackwater [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Noncash or Part Noncash Acquisition, Net Nonmonetary Assets Acquired (Liabilities Assumed)	22,121,000	0	0
ArcLight [Member] | Parent [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Noncash or Part Noncash Acquisition, Net Nonmonetary Assets Acquired (Liabilities Assumed)	59,995,000	'	'
Blackwater [Member] | Parent [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Noncash or Part Noncash Acquisition, Net Nonmonetary Assets Acquired (Liabilities Assumed)	$22,121,000	'	'

Liquidity_Details

Liquidity (Details) (USD $)

12 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

Apr. 15, 2013

Dec. 17, 2013

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2013

Apr. 15, 2013

Maximum [Member]

Maximum [Member]

Eurodollar [Member]

Debt Instrument, Third Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Blackwater [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

Series A [Member]

Eurodollar [Member]

Eurodollar [Member]

Base Rate [Member]

Base Rate [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

Fourth Amendment [Member]

ArcLight [Member]

Blackwater [Member]

Repayment of Debt [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Fiscal Quarter Ending December 31, 2014 [Member]

Fiscal Quarter Ending June 30, 2013 [Member]

Fiscal Quarter Ending Semptember 30, 2013 [Member]

Fiscal Quarter Ending December 31, 2013 [Member]

Fiscal Quarter Ending March 31, 2014 [Member]

Fiscal Quarter Ending June 30, 2014 [Member]

Fiscal Quarter Ending September 30, 2014 [Member]

Fiscal Quarter Ending December 31, 2014 [Member]

Fiscal Quarter Ending March 31, 2015 and thereafter [Member]

Revolving Credit Facility [Member]

Fiscal Quarter Ending December 31, 2014 [Member]

Fiscal Quarter Ending December 31, 2014 [Member]

Fiscal Quarter Ending December 31, 2014 [Member]

Fiscal Quarter Ending December 31, 2014 [Member]

Fourth Amendment [Member]

Liquidity Disclosures [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available liquidity: cash on hand and unused credit

$64,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash and cash equivalents

393,000

576,000

871,000

63,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Leverage ratio requirement

'

'

'

'

'

'

'

4

'

'

'

'

'

'

5.9

5.9

5.75

5.75

5.75

5.5

5.25

4.5

'

'

'

'

'

'

Ratio of indebtedness to net capital

3.7

5.7

'

'

5.75

4,500

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt

130,735,000

128,285,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Facility fee (percent)

'

'

'

'

'

'

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments on long-term debt

131,571,000

59,230,000

120,670,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12,500,000

Line of Credit Facility, Maximum Borrowing Capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20,000,000

'

'

'

'

'

Amount outstanding

130,735,000

128,285,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Remaining Borrowing Capacity

64,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Basis spread on variable rate

'

'

'

'

'

'

'

'

2.50%

4.75%

1.50%

3.75%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Amount Outstanding Limit

200,000,000

'

'

'

'

'

'

'

'

'

'

'

175,000,000

200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Contributions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$12,500,000

$13,000

$12,500,000

$22,696,000

'

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	12 Months Ended			3 Months Ended	12 Months Ended		0 Months Ended		0 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Mar. 31, 2014	Jan. 22, 2014	Dec. 31, 2013	Apr. 15, 2013	Apr. 15, 2013	Apr. 15, 2013
				Subsequent Event [Member]	Subsequent Event [Member]	Eurodollar [Member]	High Point [Member]	Issuance of Preferred Units [Member]	Cash Distribution [Member]
							AIM Midstream Holdings [Member]	Series A [Member]	Series A [Member]
							Partnership Interest [Member]	High Point [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'
Distribution Made to Member or Limited Partner, Distributions Declared, Per Unit	'	'	'	$0.45	$1.81	'	'	'	'
Partnership cancellation of subordinated units (percent)	'	'	'	'	'	'	90.00%	'	'
Contributed capital	'	'	'	'	'	'	'	$5,142,857	'
Payments on long-term debt	$131,571,000	$59,230,000	$120,670,000	'	'	'	'	'	'
Earned and paid (usd per unit)	'	'	'	'	'	'	'	'	$0.25
Facility fee (percent)	'	'	'	'	'	1.00%	'	'	'

Subsequent_Events_Subsequent_e

Subsequent Events Subsequent events (Details) (USD $)	3 Months Ended		3 Months Ended		12 Months Ended		3 Months Ended
	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Mar. 31, 2014	Jan. 22, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014
			PVA Assets [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Series B [Member]	Minimum [Member]	Maximum [Member]
			mi			Issuance of Preferred Units [Member]	PVA Assets [Member]	PVA Assets [Member]
			hp				in	in
Subsequent Event [Line Items]	'	'	'	'	'	'	'	'
Diameters Length Ranging	'	'	'	'	'	'	4	8
Compressor Stations Compression Capacity Horsepower	'	'	9,000	'	'	'	'	'
Distribution Made to Member or Limited Partner, Distributions Declared, Per Unit	'	'	'	$0.45	$1.81	'	'	'
Gathering pipeline (miles)	'	'	120	'	'	'	'	'
Proceeds from Issuance of Convertible Preferred Units	$87,300,000	'	'	'	'	'	'	'
Preferred Units, Contributed Capital	'	'	'	'	'	1,168,225	'	'
Business Acquisition, Cost of Acquired Entity, Purchase Price	'	$6,500,000	'	'	'	'	'	'