Third Coast Midstream (AMID) 10-Q 8 Aug 16 2016 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Aug. 05, 2016	Dec. 31, 2015
Document Information [Line Items]
Entity Registrant Name	American Midstream Partners, LP
Entity Central Index Key	1,513,965
Document Type	10-Q
Document Period End Date	Jun. 30, 2016
Amendment Flag	false
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		31,154,636
Series A Preferred Stock [Member]
Document Information [Line Items]
Convertible preferred, units, outstanding	9,797,000	9,797,342	9,210,000
Convertible preferred, units, issued	9,797,000		9,210,000
Series C Preferred Stock [Member]
Document Information [Line Items]
Convertible preferred, units, outstanding	8,571,000		0
Convertible preferred, units, issued	8,571,000	8,571,000	0

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Current assets
Cash and cash equivalents	$ 754	$ 0
Accounts receivable	8,875	3,181
Unbilled revenue	18,817	15,559
Risk management assets	944	365
Other current assets	13,348	10,094
Total current assets	42,738	29,199
Property, plant and equipment, net	683,109	648,013
Goodwill	16,262	16,262
Intangible assets, net	98,790	100,965
Investment in unconsolidated affiliates	295,572	82,301
Other assets, net	14,497	14,556
Total assets	1,150,968	891,296
Current liabilities
Accounts payable	4,811	4,667
Accrued gas purchases	9,566	7,281
Accrued expenses and other current liabilities	37,077	25,035
Current portion of long-term debt	731	2,338
Risk management liabilities	832	0
Total current liabilities	53,017	39,321
Risk management liabilities	2,556	0
Asset retirement obligations	43,430	28,549
Other liabilities	399	1,001
Long-term debt	672,400	525,100
Deferred tax liability	6,661	5,826
Total liabilities	778,463	599,797
Equity and partners' capital
General Partner Interests (664 thousand and 536 thousand units issued and outstanding as of June 30, 2016 and December 31, 2015, respectively)	(100,624)	(104,853)
Accumulated other comprehensive income (loss)	75	40
Total partners’ capital	72,291	117,257
Noncontrolling interests	7,489	4,530
Total equity and partners' capital	79,780	121,787
Total liabilities, equity and partners' capital	1,150,968	891,296
Series A Preferred Stock [Member]
Current liabilities
Convertible preferred units	176,335	169,712
Series C Preferred Stock [Member]
Current liabilities
Convertible preferred units	116,390	0
Limited Partner Common Units [Member]
Equity and partners' capital
Limited Partner Interests	172,840	188,477
Limited Partner Series B Convertible Units [Member]
Equity and partners' capital
Limited Partner Interests	$ 0	$ 33,593

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Parenthetical) (Unaudited) - shares	Aug. 05, 2016	Jun. 30, 2016	Dec. 31, 2015
General partner interest, units issued		664,000	536,000
Series A Preferred Stock [Member]
Convertible preferred, units, issued		9,797,000	9,210,000
Convertible preferred, units, outstanding	9,797,342	9,797,000	9,210,000
Limited Partner Series B Convertible Units [Member]
Units Issued		0	1,350,000
Series C Preferred Stock [Member]
Convertible preferred, units, issued	8,571,000	8,571,000	0
Convertible preferred, units, outstanding		8,571,000	0
Limited Partner Common Units [Member]
Units Issued		31,146,000	30,427,000
Partnership Interest [Member]
General partner interest units,outstanding		664,000	536,000
Partnership Interest [Member] | Limited Partner Common Units [Member]
Preferred, units, outstanding		31,146,000	30,427,000
Series B [Member] | Limited Partner Series B Convertible Units [Member]
Preferred, units, outstanding		0	1,350,000

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenue		$ 56,148	$ 67,198	$ 102,271	$ 131,660
Gain (loss) on commodity derivatives, net		(766)	311	(869)	458
Total revenue		55,382	67,509	101,402	132,118
Operating expenses:
Purchases of natural gas, NGLs and condensate		22,102	33,334	39,014	62,311
Direct operating expenses		16,191	13,967	30,712	27,834
Selling, general and administrative expenses		11,432	5,571	19,966	12,506
Equity compensation expense		1,025	550	2,109	2,248
Depreciation, amortization and accretion expense		10,903	9,250	20,997	18,939
Total operating expenses		61,653	62,672	112,798	123,838
Gain (loss) on sale of assets, net		80	(2,970)	90	(2,978)
Operating income (loss)		(6,191)	1,867	(11,306)	5,302
Interest expense		(8,507)	(3,556)	(14,379)	(6,166)
Earnings in unconsolidated affiliates		11,647	4	18,990	171
Net income (loss) before income tax (expense) benefit		(3,051)	(1,685)	(6,695)	(693)
Income tax (expense) benefit		(540)	(317)	(860)	(473)
Net income (loss) from continuing operations		(3,591)	(2,002)	(7,555)	(1,166)
Income (loss) from discontinued operations, net of tax		0	(31)	0	(26)
Net income (loss)		(3,591)	(2,033)	(7,555)	(1,192)
Net income (loss) attributable to noncontrolling interests		992	32	979	46
Net income (loss) attributable to the Partnership		$ (4,583)	$ (2,065)	$ (8,534)	$ (1,238)
Distribution declared per common unit (a)	[1]	$ 0.4125	$ 0.4725	$ 0.8850	$ 0.9450
Net Income (Loss), Per Outstanding Limited Partnership Unit, Basic, Net of Tax		$ (0.36)	$ (0.35)	$ (0.69)	$ (0.53)
Weighted Average Number of Shares Outstanding, Basic		30,949	22,757	30,884	22,730
General Partner [Member]
Operating expenses:
General Partner's Interest in net income (loss)		$ (61)	$ (25)	$ (113)	$ (14)
Limited Partner [Member]
Operating expenses:
Limited Partners' Interest in net income (loss)		$ (4,522)	$ (2,040)	$ (8,421)	$ (1,224)
[1]	Distributions declared and paid each quarter related to prior periods' quarter.

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Net income (loss)	$ (3,591)	$ (2,033)	$ (7,555)	$ (1,192)
Comprehensive income (loss)	(3,570)	(2,056)	(7,520)	(1,226)
Net income (loss) attributable to noncontrolling interests	992	32	979	46
Comprehensive income (loss) attributable to the Partnership	(4,562)	(2,088)	(8,499)	(1,272)
Accumulated Other Comprehensive Income (Loss) [Member]
Unrealized gain (loss) on postretirement benefit plan assets and liabilities	$ 21	$ (23)	$ 35	$ (34)

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Changes in Partners' Capital (Unaudited) - USD ($) $ in Thousands	Total	General Partner [Member]	Limited Partner [Member]	Series B [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Parent [Member]	Noncontrolling Interest [Member]	Series B [Member]	Series B [Member]Series B [Member]	Series B [Member]Accumulated Other Comprehensive Income (Loss) [Member]	Series B [Member]Parent [Member]	Series B [Member]Noncontrolling Interest [Member]	Costar Midstream, L.L.C. [Member]	At the Market Offering [Member]
Partners' Capital		$ (2,450)	$ 294,695	$ 32,220	$ 2	$ 324,467	$ 4,717
Partners' Capital		(5,218)	265,319	33,053	(32)	293,122	4,693
Net Income (Loss) Allocated to General Partners		(14)
Net Income (Loss) Allocated to Limited Partners			(1,224)
Net income (loss)	$ (1,192)
Net income (loss) attributable to the Partnership	(1,238)					(1,238)
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest							46
Net income (loss) attributable to noncontrolling interests	46
Proceeds from Issuance of Preferred Stock and Preference Stock									$ 833
Cancellation of escrow units													$ 0
Conversion/Issuance of units									(833)
Unitholder contributions		376	0		0	376
Unitholder distributions	(24,364)	(3,004)	(29,800)			(32,804)		$ (833)
Net distributions to noncontrolling interests		0	0		0	0	(70)
LTIP vesting		(2,178)	2,373			195
LTIP tax netting unit repurchase	725		(725)			(725)
Equity compensation expense		2,052				2,052
Unrealized gain (loss) on postretirement benefit plan assets and liabilities					(34)	(34)
Partners' Capital at Jun. 30, 2015		(5,218)	265,319	33,053	(32)	293,122	4,693
Partners' Capital		(5,218)	265,319	33,053	(32)	293,122	4,693
Partners' Capital	117,257	(104,853)	188,477	33,593	40	117,257	4,530
Partners' Capital	72,291	(100,624)	172,840	0	75	72,291	7,489
Net Income (Loss) Allocated to General Partners		(113)
Net Income (Loss) Allocated to Limited Partners			(8,421)
Net income (loss)	(7,555)
Net income (loss) attributable to the Partnership	(8,534)					(8,534)	979
Net income (loss) attributable to noncontrolling interests	979
Issuance of common units, net of offering costs		0	2,986	0	0		0
Cancellation of escrow units													$ (6,817)
Conversion/Issuance of units			33,593						$ (33,593)	$ 0	$ 0	$ 0		$ 0
Stock and Warrants Issued During Period, Value, Preferred Stock and Warrants	4,481
Unitholder contributions		1,791	0	0		1,791	0
Unitholder distributions	(29,964)	(2,351)	(38,935)			(41,286)		$ 0
Unitholder contribution for acquisitions		990
Net distributions to noncontrolling interests		0	0	0	0	0	149
Acquisition of noncontrolling interest		0	0	0	0	0	1,831
LTIP vesting		(2,107)	2,107			0
LTIP tax netting unit repurchase	150		(150)	0		(150)
Equity compensation expense		1,538	0	0	0	1,538	0
Unrealized gain (loss) on postretirement benefit plan assets and liabilities					35	35
Partners' Capital at Jun. 30, 2016	72,291	(100,624)	172,840	0	75	72,291	7,489
Partners' Capital	$ 72,291	$ (100,624)	$ 172,840	$ 0	$ 75	$ 72,291	$ 7,489

Condensed Consolidated Stateme7

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Net income (loss)	$ (7,555)	$ (1,192)
Depreciation, amortization and accretion expense	20,997	18,939
Amortization of deferred financing costs	1,030	667
Amortization of weather derivative premium	451	475
Unrealized (gain) loss on commodity derivatives, net	3,388	(213)
Non-cash compensation	2,109	2,294
Postretirement expense (benefit)	0	18
(Gain) loss on sale of assets, net	(90)	2,978
Earnings in unconsolidated affiliates	(18,990)	(171)
Distributions from unconsolidated affiliates	18,990	171
Deferred tax expense (benefit)	835	457
Accounts receivable	(5,694)	(1,331)
Unbilled revenue	(3,258)	5,964
Risk management assets and liabilities	(1,030)	(875)
Other current assets	1,753	1,041
Other assets, net	700	37
Accounts payable	1,136	6,200
Accrued gas purchases	2,285	(4,709)
Accrued expenses and other current liabilities	2,303	(1,293)
Asset retirement obligations	(10)	0
Other liabilities	(673)	163
Net cash provided by operating activities	18,677	29,620
Cost of acquisitions, net of cash acquired and settlements	(3,073)	7,383
Additions to property, plant and equipment	(40,242)	(79,734)
Investment in unconsolidated affiliates	(11,444)	(626)
Proceeds from disposals of property, plant and equipment	137	3,876
Distributions from unconsolidated affiliates, return of capital	16,728	1,329
Restricted cash	0	6,475
Net cash used in investing activities	(138,802)	(61,297)
Proceeds from issuance of common units to public, net of offering costs	3,004	(348)
Unitholder contributions	1,791	330
Unitholder distributions	(29,964)	(24,364)
Issuance of Units, net of issuance costs	0	45,000
Acquisition of noncontrolling interests	1,831	0
LTIP tax netting unit repurchase	(150)	(725)
Deferred financing costs	(1,475)	(276)
Payments on other debt	(1,607)	(2,171)
Payments on long-term debt	(64,900)	(123,650)
Borrowings on long-term debt	212,200	137,800
Net cash provided by financing activities	120,879	31,526
Net increase (decrease) in cash and cash equivalents	754	(151)
Beginning of period	0	499
End of period	754	348
Interest payments, net	12,603	5,572
(Decrease) increase in accrued property, plant and equipment	3,221	(16,897)
Total Consideration for Issuance of Preferred Units	120,000	0
Accrued Cash Dividends Paid to Parent Company by Unconsolidated Affiliates	(4,360)	0
Series A [Member]
Accrued and paid-in-kind unitholder distribution for Units	2,200
Paid-in-kind unitholder distribution for Series B Units	0	833
Noncontrolling Interest [Member]
Net contributions from (distributions to) noncontrolling interests	149	(70)
Costar Midstream, L.L.C. [Member]
Cancellation of escrow units	6,817	0
Series A Preferred Stock [Member]
Accrued and paid-in-kind unitholder distribution for Units	9,100	7,600
Series C Preferred Stock [Member]
Accrued and paid-in-kind unitholder distribution for Units	2,249	0
Emerald Transaction [Member]
Investment in unconsolidated affiliates	$ (100,908)	$ 0

Organization and Basis of Prese

Organization and Basis of Presentation	6 Months Ended
	Jun. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation	Organization, Basis of Presentation and Summary of Significant Accounting Policies General American Midstream Partners, LP (the "Partnership", "we", "us", or "our") was formed on August 20, 2009 as a Delaware limited partnership for the purpose of owning, operating, developing and acquiring a diversified portfolio of midstream energy assets. The Partnership's general partner, American Midstream GP, LLC (the "General Partner"), is 95% owned by High Point Infrastructure Partners, LLC ("HPIP") and 5% owned by AIM Midstream Holdings, LLC. We hold our assets primarily in a number of limited liability companies, two limited partnerships and a corporation. Our capital accounts consist of notional general partner units and limited partner interests. Nature of Business We are engaged in the business of gathering, treating, processing and transporting natural gas; gathering, transporting, storing, treating and fractionating NGLs; gathering, storing and transporting crude oil and condensates; and storing specialty chemical products, all through our ownership and operation of 13 gathering systems, five processing facilities, three fractionation facilities, three interstate pipelines, five intrastate pipelines, three marine terminal sites and one crude oil pipeline. Our primary assets, which are strategically located in Alabama, Georgia, Louisiana, Mississippi, North Dakota, Tennessee, Texas and the Gulf of Mexico, provide critical infrastructure that links producers of natural gas, crude oil, NGLs, condensate and specialty chemicals to numerous intermediate and end-use markets. We currently operate more than 3,000 miles of pipelines that gather and transport over 1 Bcf/d of natural gas and operate approximately 2.2 million barrels of storage capacity across three marine terminal sites. Basis of Presentation These unaudited condensed consolidated financial statements have been prepared in accordance with GAAP for interim financial information. Accordingly, they do not include all of the information and footnotes required by GAAP for annual financial statements. The year-end balance sheet data was derived from consolidated audited financial statements but does not include disclosures required by GAAP for annual periods. The information furnished herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for a fair statement of financial position and results of operations for the respective interim periods. Our financial results for the three and six months ended June 30, 2016 , are not necessarily indicative of the results that may be expected for the year ending December 31, 2016 . These unaudited condensed consolidated financial statements should be read in conjunction with our consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2015 , filed with the Securities and Exchange Commission (the "SEC") on March 7, 2016 (“Annual Report”). Consolidation Policy The accompanying condensed consolidated financial statements include the 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 condensed consolidated financial statements. Investment in Unconsolidated Affiliates We hold various non-operated membership interests in entities that own and operate natural gas pipeline systems, NGL and crude oil pipelines in and around Louisiana, Alabama, Mississippi and the Gulf of Mexico. These non-operated membership interests in which the Partnership exercises significant influence, but does not control and is not the primary beneficiary, are accounted for using the equity method and are reported in Investment in unconsolidated affiliates in the accompanying condensed consolidated balance sheets. The Partnership believes the equity method is an appropriate means to recognize increases or decreases, measured by GAAP, in the economic resources underlying the investments. Regular evaluation of these investments is appropriate to evaluate any potential need for impairment. The Partnership uses evidence of a loss in value to identify if an investment has incurred an other than temporary decline. Use of Estimates When preparing condensed consolidated 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 assumptions are based on information available at the time such estimates and assumptions are made. Adjustments made with respect to the use of these estimates and assumptions often relate to information not previously available. Uncertainties with respect to such estimates and assumptions are inherent in the preparation of financial statements. Estimates and assumptions 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. Recent Accounting Pronouncements In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2014-09, Revenue from Contracts with Customers (Topic 606), which amends the existing accounting standards for revenue recognition. The standard requires an entity to recognize revenue in a manner that depicts the transfer of goods or services to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2015-14 was subsequently issued and deferred the effective date to annual reporting periods beginning after December 15, 2017, including interim reporting periods within that period. In March 2016, the FASB issued ASU No. 2016-08, Revenue from Contracts with Customers (Topic 606) - Principal Versus Agent Considerations , as further clarification on principal versus agent considerations. Subsequently, in April 2016, the FASB issued ASU 2016-10, Revenue from Contracts with Customers (Topic 606)-Identifying Performance Obligations and Licensing as further clarification on identifying performance obligations and the licensing implementation guidance. In May 2016, the FASB issued ASU 2016-12, Revenue from Contracts with Customers (Topic 606)-Narrow-Scope Improvements and Practical Expedients , as clarifying guidance on specific narrow scope improvements and practical expedients. The Partnership is currently evaluating the adoption of these standards and their impact on its consolidated financial statements and related disclosures. In February 2015, the FASB issued ASU No. 2015-02, Consolidation - Amendments to the Consolidation Analysis, which amends the current consolidation guidance. The amendments affect both the variable interest entity ("VIE") and voting interest entity ("VOE") consolidation models. The standard is effective for public reporting entities in the fiscal periods beginning after December 15, 2015. The Partnership reviewed its VIEs and VOEs in connection with the adoption of this standard and determined no change to its previous conclusions was required. In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842). This amendment requires the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under previous GAAP. ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early adoption is permitted. The Partnership is currently evaluating the method of adoption and impact this standard will have on its consolidated financial statements and related disclosures. In March 2016, the FASB issued ASU No. 2016-06, Derivatives and Hedging (Topic 815). This amendment clarifies existing guidance for assessing embedded call (put) options that are closely related to their debt hosts using a four-step decision sequence. ASU 2016-06 is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Early adoption is permitted. The Partnership has evaluated this guidance and determined it will not have a material impact on its consolidated financial statements and related disclosures. In March 2016, the FASB issued ASU No. 2016-07, Investments - Equity Method and Joint Ventures (Topic 323). This amendment eliminates the requirement to retroactively adopt the equity method of accounting when a previous investment becomes qualified as a result of an increase in the level of ownership interest or degree of influence. ASU 2016-07 is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal periods. Early adoption is permitted. The Partnership has evaluated this guidance and determined it will not have a material impact on its consolidated financial statements and related disclosures. In March 2016, the FASB issued ASU No. 2016-09, Compensation - Stock Compensation (Topic 718). This amendment involves the simplification of several aspects of accounting for share-based payment transactions, including income tax consequences, classification of awards as either equity or liability, and classification on the statement of cash flows. ASU 2016-09 is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal periods. Early adoption is permitted. The Partnership is currently evaluating the method of adoption and impact this standard will have on its consolidated financial statements and related disclosures.

Acquisitions and Divestitures

Acquisitions and Divestitures	6 Months Ended
	Jun. 30, 2016
Business Combinations [Abstract]
Acquisitions and Divestitures	Acquisitions Emerald Transactions On April 25, 2016 and April 27, 2016, American Midstream Emerald, LLC ("Emerald"), a wholly-owned subsidiary of the Partnership, entered into two purchase and sale agreements with Emerald Midstream, LLC, an affiliate of ArcLight Capital Partners, LLC ("ArcLight"), the majority owner of our General Partner, for the purchase of membership interests in certain midstream entities. On April 25, 2016, Emerald entered into the first purchase and sale agreement for the purchase of membership interests in entities that own and operate natural gas pipeline systems and NGL pipelines in and around Louisiana, Alabama, Mississippi, and the Gulf of Mexico (the "Pipeline Purchase Agreement"). Pursuant to the Pipeline Purchase Agreement, Emerald acquired (i) 49.7% of the issued and outstanding membership interests of Destin Pipeline Company, L.L.C. ("Destin"), (ii) 16.7% of the issued and outstanding membership interests of Tri-States NGL Pipeline, L.L.C. ("Tri-States"), and (iii) 25.3% of the issued and outstanding membership interests of Wilprise Pipeline Company, L.L.C. ("Wilprise" and collectively with Destin and Tri-States, the "Companies"), in exchange for approximately $183.6 million (the "Pipeline Transaction"). The Destin pipeline is a FERC-regulated, 255 -mile natural gas transportation system with total capacity of 1.2 Bcf/d. The system originates offshore in the Gulf of Mexico and includes connections with four producing platforms, and six producer-operated laterals, including the Partnership's non-operated indirect interest in the Delta House floating production system and related pipeline infrastructure ("Delta House"). The 120 -mile offshore portion of the Destin system terminates at the Pascagoula processing plant, owned by Enterprise Products Partners, LP, is the single source of raw natural gas to the plant. The onshore portion of Destin is the sole delivery point for merchant-quality gas from the Pascagoula processing plant and extends 135 miles north in Mississippi. Destin currently serves as the primary transfer of gas flows from the Barnett and Haynesville shale plays to Florida markets through interconnections with major interstate pipelines. Contracted volumes on the Destin pipeline are based on life-of-field dedication, dedicated volumes over a given period, or interruptible volumes as capacity permits. The Tri-States pipeline is a FERC-regulated, 161 -mile natural gas liquids ("NGL") pipeline and sole form of transport to Louisiana-based fractionators for NGLs produced at the Pascagoula plant served by Destin and other facilities. The Wilprise pipeline is a FERC-regulated, approximately 30 -mile NGL pipeline that originates at the Kenner Junction and terminates in Sorrento, Louisiana, where volumes flow via pipeline to a Baton Rouge fractionator. On April 27, 2016, Emerald entered into a second purchase and sale agreement for the purchase of 66.7% of the issued and outstanding membership interests of Okeanos Gas Gathering Company, LLC ("Okeanos"), in exchange for a cash purchase price of approximately $27.4 million (such Purchase and Sale Agreement, the "Okeanos Purchase Agreement," and such transaction, the "Okeanos Transaction," and together with the Pipeline Transaction, the "Emerald Transactions"). The Okeanos pipeline is a 100 -mile natural gas gathering system located in the Gulf of Mexico with a total capacity of 1.0 Bcf/d. The Okeanos pipeline connects two platforms and one lateral, terminating at the Destin Main Pass 260 platform in the Mississippi Canyon region of the Gulf of Mexico. Contracted volumes on the Okeanos pipeline are based on life-of-field dedication. The Partnership funded the aggregate purchase price for the Emerald Transactions with the issuance of 8,571,429 shares of newly-designated Series C convertible preferred units (the “Series C Units”) representing limited partnership interests in the Partnership and a warrant (the “Warrant”) to purchase up to 800,000 common units representing limited partnership interests in the Partnership ("common units") at an exercise price of $7.25 per common unit amounting to a combined value of approximately $120.0 million , plus additional borrowings of $91.0 million under our Credit Agreement (as defined herein). Affiliates of our General Partner hold and participate in distributions on our Series C Units with such distributions being made in paid-in-kind Series C Units, cash or a combination thereof at the election of the Board of Directors of our General Partner. Because our interests in the entities underlying the Emerald Transactions were previously owned by an affiliate of our General Partner, we accounted for our investments at our affiliate's carry-over basis of $212.0 million , which is recorded in Investment in unconsolidated affiliates in our condensed consolidated balance sheets, and as an investing activity of $ 100.9 million within the condensed consolidated statements of cash flows. The amount by which the carry-over basis exceeded total consideration was $1.0 million and is recorded as a contribution from our General Partner within the condensed consolidated statements of changes in partners’ capital and noncontrolling interests. Pursuant to the individual limited liability company or operating agreements for the entities acquired in the Emerald Transactions, we have no management control or authority over the day-to-day operations over the assets acquired in the Emerald Transactions. Our interests acquired in the entities underlying the Emerald Transactions are accounted for as investments in unconsolidated affiliates in the condensed consolidated financial statements. For the three-months ended June 30, 2016, the Partnership recorded $4.2 million in earnings and received cash distributions of $5.4 million from the entities underlying the Emerald Transactions. The excess of the cash distributions received over the earnings recorded is classified as proceeds from Investment in unconsolidated affiliates, return of capital within cash flows from investing activities in our condensed consolidated statement of cash flows. Gulf of Mexico Pipelines On April 15, 2016, American Panther, LLC ("American Panther"), a 60% -owned subsidiary of the Partnership, acquired approximately 200 miles of crude oil, natural gas, and salt water onshore and offshore Gulf of Mexico pipelines ("Gulf of Mexico Pipeline") for approximately $3.1 million in cash and the assumption of certain asset retirement obligations. The Partnership exerts control over American Panther and therefore consolidates its financial activity for financial reporting purposes. The acquisition was accounted for using the acquisition method of accounting and as a result, the aggregate purchase price was allocated to the assets acquired and liabilities assumed based on their respective fair values as of the acquisition date. The following tables summarize the fair value of consideration transferred by the Partnership for the acquisition and the preliminary allocation of that amount to the assets acquired and liabilities assumed based on their respective fair values as of the acquisition date (in thousands). Fair value of consideration transferred: Cash $ 3,073 Fair value of assets acquired, liabilities assumed: Assets: Property, plant and equipment: Pipelines $ 16,952 Land 421 Total property, plant and equipment 17,373 Liabilities: Asset retirement obligations (14,300 ) Fair value of net assets acquired and liabilities assumed $ 3,073 American Panther contributed revenue of $4.3 million and net income of $2.6 million for the period of April 15, 2016 through June 30, 2016, which is included in the Partnership's Gathering and Processing segment. Additionally, the Partnership incurred $0.2 million of transaction costs related to the acquisition which are included in Selling, general and administrative expenses in our condensed consolidated statement of operations for the three months ended June 30, 2016. Pro forma financial results are not presented as it is impractical to obtain the necessary information. The seller did not operate the acquired assets as a standalone business and, therefore, historical financial information is not available. Additional Delta House Investment On April 25, 2016, American Midstream Delta House, LLC ("AMID Delta House"), a wholly-owned subsidiary of the Partnership, entered into a unit purchase agreement with an affiliate of ArcLight, pursuant to which AMID Delta House acquired 100% of the outstanding membership interests in D-Day Offshore Holdings, LLC ("D-Day"), which owned (i) 912.4 Class A Units of Delta House FPS LLC and (ii) 53.5 Class A Units of Delta House Oil and Gas Lateral LLC in exchange for a cash purchase price of approximately $9.9 million funded with additional borrowings under the Partnership’s Credit Agreement. Delta House is a floating production system platform with associated crude oil and natural gas export pipelines, located in the Mississippi Canyon region of the deepwater Gulf of Mexico. Because our interest in D-Day was previously owned by an affiliate of our General Partner, we have accounted for our investment at our affiliate's carry-over basis of $9.9 million , which is recorded in Investments in unconsolidated affiliates in our condensed consolidated balance sheets and as an investing activity within the condensed consolidated statements of cash flows. For the three-months ended June 30, 2016, the Partnership recorded $0.4 million in earnings and received cash distributions of $1.1 million from its D-Day investment. The excess of the cash distributions received over the earnings recorded is classified as a return of capital within cash flows from investing activities in our condensed consolidated statements of cash flows. The investment in D-Day, together with our 26.3% interest in Pinto Offshore Holdings, LLC, an entity that owns a 49.0% non-operated interest in Delta House, results in the Partnership holding a combined 13.9% non-operated indirect interest in Delta House. Pursuant to the agreements governing the underlying entities, we have no management control or authority over the day-to-day operations of Delta House. Our interests in Delta House are accounted for as investments in unconsolidated affiliates in the condensed consolidated financial statements. Divestitures On June 1, 2015, the Partnership disposed of certain non-strategic off-shore transmission assets in Louisiana with a net book value of $3.0 million for nominal proceeds, resulting in a non-cash loss on disposal of $3.0 million .

Concentration of Credit Risk an

Concentration of Credit Risk and Trade Accounts Receivable	6 Months Ended
	Jun. 30, 2016
Risks and Uncertainties [Abstract]
Concentration of Credit Risk and Trade Account Receivable	Concentration of Credit Risk and Trade Accounts Receivable Our primary assets, which are strategically located in Alabama, Georgia, Louisiana, Mississippi, North Dakota, Tennessee, Texas and the Gulf of Mexico, provide critical infrastructure that links customers of crude oil, natural gas, NGLs, condensate and specialty chemicals to numerous intermediate and end-use markets. As a result of recent acquisitions and geographic diversification, we have reduced the concentration of trade receivable balances due from these customer groups. 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 three and six months ended June 30, 2016 and 2015 , no allowances on or significant write-offs of accounts receivable were recorded. During the three and six months ended June 30, 2016 , one customer accounted for 10% and 11% , respectively, of the Partnership's consolidated revenue. During the three and six months ended June 30, 2015, no individual customer accounted for 10% or more of the Partnership's consolidated revenue.

Other Current Assets (Notes)

Other Current Assets (Notes)	6 Months Ended
	Jun. 30, 2016
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of Other Current Assets	Other current assets consisted of the following (in thousands): June 30, December 31, 2016 2015 Prepaid insurance $ 3,073 $ 3,948 Accrued distributions from unconsolidated affiliates 4,359 — Other prepaid amounts 2,108 2,866 Other current assets 3,808 3,280 $ 13,348 $ 10,094

Derivatives

Derivatives	6 Months Ended
	Jun. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives Commodity Derivatives To limit the effect of commodity price changes and maintain our cash flow and the economics of our development plans, we enter into commodity derivative contracts from time to time. The terms of the contracts depend on various factors, including management's view of future commodity prices, economics on purchased assets and future financial commitments. The hedging program is designed to mitigate the effect of commodity price declines while allowing us to participate in commodity price increases. 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, our commodity derivatives are in the form of swaps. As of June 30, 2016 , the aggregate notional volume of our commodity derivatives was 5.6 million gallons of NGLs, natural gasoline and crude oil equivalent for 2016 production. We enter into commodity derivative contracts with multiple counterparties, and in some cases, may be required to post collateral with our counterparties in connection with our derivative positions. As of June 30, 2016 , we were not required to post collateral with any counterparty. The counterparties are not required to post collateral with us in connection with their derivative positions. Netting agreements are in place that permit us to offset our commodity derivative asset and liability positions with our counterparties. We did not designate any of our commodity derivatives as hedges for accounting purposes. As a result, our commodity derivatives are accounted for at fair value in our condensed consolidated balance sheets with changes in fair value recognized currently in earnings. Interest Rate Swaps To manage the impact of the interest rate risk associated with our Credit Agreement, we enter into interest rate swaps from time to time, effectively converting a portion of the cash flows related to our long-term variable rate debt into fixed rate cash flows. As of June 30, 2016 , the total notional amount of our interest rate swaps was $300.0 million . In the first quarter of 2016, we entered into interest rate swaps with a notional amount of $200.0 million . The interest rate swaps were entered into with a single counterparty and we were not required to post collateral. The interest rate swaps will expire September 3, 2019. In the second quarter of 2016, we entered into additional interest rate swaps with a notional amount of $100.0 million . The interest rate swaps were entered into with a single counterparty and we were not required to post collateral. The interest rate swaps are effective beginning January 1, 2018 and will expire December 31, 2021. Weather Derivative In the second quarter of 2016, we entered into a weather derivative to mitigate the impact of potential unfavorable weather on our operations under which we could receive payments totaling up to $30.0 million in the event that a hurricane or hurricanes of certain strength pass through the areas identified in the derivative agreement. The weather derivative is accounted for using the intrinsic value method. The weather derivative was entered into with a single counterparty and we were not required to post collateral. We paid premiums of $1.0 million and $0.9 million during the six months ended June 30, 2016 and 2015, respectively, which were recorded as current Risk management assets on our condensed consolidated balance sheet and are being amortized to Direct operating expenses on a straight-line basis over the term of the contract of one year . Unamortized amounts associated with the weather derivatives were approximately $0.9 million as of June 30, 2016 . As of June 30, 2016 and December 31, 2015 , the value associated with our commodity derivatives, interest rate swaps, and weather derivative were recorded in our condensed consolidated balance sheets as follows (in thousands): Gross Risk Management Assets Gross Risk Management (Liabilities) Net Risk Management Assets (Liabilities) Balance Sheet Classification June 30, December 31, 2015 June 30, December 31, 2015 June 30, December 31, 2015 Current $ 944 $ 365 $ — $ — $ 944 $ 365 Noncurrent — — — — — — Total assets $ 944 $ 365 $ — $ — $ 944 $ 365 Current $ — $ — $ (832 ) $ — $ (832 ) $ — Noncurrent — — (2,556 ) — (2,556 ) — Total liabilities $ — $ — $ (3,388 ) $ — $ (3,388 ) $ — For the three and six months ended June 30, 2016 and 2015 , respectively, the realized and unrealized gains (losses) associated with our commodity derivatives, interest rate swaps and weather derivative were recorded in our condensed consolidated statements of operations as follows (in thousands): Three months ended June 30, Six months ended June 30, Gain (loss) on Derivatives Gain (loss) on derivatives Statement of Operations Classification Realized Unrealized Realized Unrealized 2016 Gain (loss) on commodity derivatives, net $ (244 ) $ (522 ) $ (244 ) $ (625 ) Interest expense — (2,033 ) — (2,763 ) Direct operating expenses (232 ) — (450 ) — Total $ (476 ) $ (2,555 ) $ (694 ) $ (3,388 ) 2015 Gain (loss) on commodity derivatives, net $ 252 $ 59 $ 391 $ 67 Interest expense (101 ) 98 (203 ) 146 Direct operating expenses (234 ) — (475 ) — Total $ (83 ) $ 157 $ (287 ) $ 213

Fair Value Measurement

Fair Value Measurement	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value Measurement	Fair Value Measurement We believe the carrying amount of cash and cash equivalents, accounts receivable and accounts payable approximates fair value because of the short-term maturity of these instruments. The recorded value of the amount outstanding under the Credit Agreement approximates its fair value, as interest rates are variable, based on prevailing market rates, and due to the short-term nature of borrowings and repayments under the Credit Agreement. The fair value of our commodity and interest rate derivatives instruments are 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 in which the transfer occurred. There were no such transfers for the six months ended June 30, 2016 and 2015 . Fair Value of Financial Instruments The following table sets forth, by level within the fair value hierarchy, our commodity derivative instruments and interest rate swaps, included as part of Risk management assets and Risk management liabilities within our condensed consolidated balance sheets, that were measured at fair value on a recurring basis as of June 30, 2016 and December 31, 2015 (in thousands): Carrying Amount Estimated Fair Value of the Assets (Liabilities) Level 1 Level 2 Level 3 Total Commodity derivative instruments, net: June 30, 2016 $ (625 ) $ — $ (625 ) $ — $ (625 ) December 31, 2015 — — — — — Interest rate swaps: June 30, 2016 $ (2,763 ) $ — $ (2,763 ) $ — $ (2,763 ) December 31, 2015 — — — — — The unamortized portion of the premium paid to enter the weather derivative described in Note 5 "Derivatives" is included within Risk management assets on our condensed consolidated balance sheets 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

Property, Plant and Equipment	6 Months Ended
	Jun. 30, 2016
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment, Net Property, plant and equipment, net, as of June 30, 2016 and December 31, 2015 were as follows (in thousands): Useful Life (in years) June 30, December 31, Land N/A $ 5,703 $ 5,282 Construction in progress N/A 61,203 46,045 Buildings and improvements 4 to 40 9,959 9,864 Processing and treating plants 8 to 40 102,003 97,784 Pipelines and compressors 3 to 40 573,084 554,400 Storage 20 to 40 58,226 58,394 Equipment 5 to 20 37,065 22,207 Total property, plant and equipment 847,243 793,976 Accumulated depreciation (164,134 ) (145,963 ) Property, plant and equipment, net $ 683,109 $ 648,013 Of the gross property, plant and equipment balances at June 30, 2016 and December 31, 2015 , $132.0 million and $111.9 million , respectively, were related to AlaTenn, American Midstream Midla, LLC ("Midla") and High Point Gathering Systems, our FERC regulated interstate and intrastate assets. Capitalized interest was $0.5 million for the three months ended June 30, 2016 and 2015 , respectively, and $ 1.0 million and $ 0.7 million for the six months ended June 30, 2016 and 2015 , respectively. Depreciation expense was $9.4 million and $7.6 million for the three months ended June 30, 2016 and 2015 , respectively, and $ 18.2 million and $ 15.5 million for the six months ended June 30, 2016 and 2015 , respectively. In February 2016, the Partnership reached a settlement of certain indemnification claims with Energy Spectrum Partners VI LP and Costar Midstream Energy, LLC, the sellers in the Partnership's acquisition of 100% of the membership interests of Costar Midstream, L.L.C. ("Costar" and such acquisition, the "Costar Acquisition"), whereby 1,034,483 of the common units held in escrow were returned to the Partnership and canceled, while the Partnership agreed to pay the Costar sellers an additional $0.7 million in cash. The net impact of this settlement was recorded as a reduction in Property, plant and equipment, net and Limited partner interests in the first half of 2016.

Goodwill and Intangible Assets,

Goodwill and Intangible Assets, Net (Notes)	6 Months Ended
	Jun. 30, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets, Net	Goodwill and Intangible Assets, Net The carrying value of goodwill as of June 30, 2016 and December 31, 2015 , all of which related to our Terminals segment, was $16.3 million . The goodwill was contributed to the Partnership as part of the acquisition of Blackwater Midstream Holdings LLC ("Blackwater") and other related subsidiaries from an affiliate of our General Partner (the "Blackwater Acquisition"). Intangible assets, net, consists of customer relationships and dedicated acreage agreements identified as part of the Costar and Lavaca acquisitions. These intangible assets have definite lives and are subject to amortization on a straight-line basis over their economic lives, currently ranging from 10 years to 30 years . Intangible assets, net, consist of the following (in thousands): June 30, December 31, 2016 2015 Gross carrying amount: Customer relationships $ 53,400 $ 53,400 Dedicated acreage 53,350 53,350 $ 106,750 $ 106,750 Accumulated amortization: Customer relationships $ (4,410 ) $ (3,124 ) Dedicated acreage (3,550 ) (2,661 ) $ (7,960 ) $ (5,785 ) Net carrying amount: Customer relationships $ 48,990 $ 50,276 Dedicated acreage 49,800 50,689 $ 98,790 $ 100,965 Amortization expense on our intangible assets totaled $1.1 million and $1.5 million for the three months ended June 30, 2016 and 2015 , respectively, and $ 2.2 million and $ 3.1 million for the six months ended June 30, 2016 and 2015 , respectively.

Investment in unconsolidated af

Investment in unconsolidated affiliates (Notes)	6 Months Ended
	Jun. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Investment in unconsolidated affiliates	Investment in unconsolidated affiliates The following table summarizes our percentage ownership interests in investments in unconsolidated affiliates: Percentage Ownership Destin 49.7 % Tri-States 16.7 % Delta House 13.9 % Wilprise 25.3 % Okeanos 66.7 % Main Pass Oil Gathering Company, LLC ("MPOG") 66.7 % Mesquite 47.3 % The following table presents the activity in the Partnership's equity investments for the six months ended June 30, 2016 (in thousands): Destin Tri-States Delta House Others (1) Total Balances at December 31, 2015 $ — $ — $ 56,525 $ 25,776 $ 82,301 Investments 122,830 56,681 9,873 32,515 221,899 Earnings in unconsolidated affiliates 2,027 869 14,264 1,830 18,990 Contributions — — — 12,459 12,459 Distributions (6,631 ) (1,092 ) (28,359 ) (3,995 ) (40,077 ) Balances at June 30, 2016 $ 118,226 $ 56,458 $ 52,303 $ 68,585 $ 295,572 (1) Includes activity associated with our non-operated interests in Wilprise, Okeanos, MPOG and Mesquite. The following tables present the summarized combined financial information for the Partnership's equity investments (amounts represent 100% of investee financial information): Balance Sheets: June 30, 2016 December 31, 2015 Current assets $ 170,283 $ 2,086 Non-current assets 1,470,286 288,617 Current liabilities 182,895 366 Non-current liabilities 475,602 23,617 Three months ended June 30, Six months ended June 30, Income Statements: 2016 2015 2016 2015 Total revenue $ 87,054 $ 1,974 $ 151,997 $ 4,410 Operating expense 6,649 768 7,541 1,738 Net income 65,613 (2 ) 120,777 241 The unconsolidated affiliates described above were each determined to be variable interest entities due to disproportionate economic interests and decision making rights. In each case, the Partnership lacks the power to direct the activities that most significantly impact each unconsolidated affiliate's economic performance. As the Partnership does not hold a controlling interest in these affiliates, the Partnership accounts for its related investments using the equity method. The Partnership’s maximum exposure to loss related to each entity is limited to its equity investment as presented on the condensed consolidated balance sheet at June 30, 2016. In each case, the Partnership is not obligated to absorb losses greater than its proportional ownership percentages indicated above. In each case, the Partnership’s right to receive residual returns is not limited to any amount less than the proportional ownership percentages indicated above.

Accrued Expenses and Other Curr

Accrued Expenses and Other Current Liabilities (Notes)	6 Months Ended
	Jun. 30, 2016
Other Liabilities Disclosure [Abstract]
Accrued Expenses and Other Current Liabilities	Accrued Expenses and Other Current Liabilities Accrued expenses and other current liabilities were as follows (in thousands): June 30, December 31, 2016 2015 Current portion of asset retirement obligation (a) $ 6,826 $ 6,822 Accrued capital expenditures 8,299 3,984 Accrued expenses 11,788 3,178 Due to related parties 2,424 3,894 Other 7,740 7,157 $ 37,077 $ 25,035 (a) Associated with certain Gathering and Processing assets.

Asset Retirement Obligations (N

Asset Retirement Obligations (Notes)	6 Months Ended
	Jun. 30, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	11. 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. six months ended June 30, 2016 (in thousands): Beginning asset retirement obligation $ 35,371 Liabilities assumed 14,300 Expenditures (11 ) Accretion expense 596 Total ending asset retirement obligation $ 50,256 Less: current portion 6,826 Long-term asset retirement obligation $ 43,430 As a result of the Gulf of Mexico Pipeline acquisition, we have recorded an additional ARO of $14.3 million . We are required to establish security against any potential secondary obligations relating to the abandonment of certain transmission assets that may be imposed on the previous owner by applicable regulatory authorities. As such, we have a restricted cash account maintained by a third party that amounted to $5.0 million as of June 30, 2016 and is presented in Other assets, net in our consolidated balance sheets.

Debt Obligations

Debt Obligations	6 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Debt Obligations	Debt Obligations Our outstanding borrowings under the credit facility were (in thousands): June 30, December 31, Revolving credit facility $ 672,400 $ 525,100 Other debt 731 2,338 Total debt 673,131 527,438 Less: current portion 731 2,338 Long-term debt $ 672,400 $ 525,100 Effective as of April 25, 2016, the Partnership entered into the Second Amendment to the Amended and Restated Credit Agreement, (as amended, the "Credit Agreement"), which provides for maximum borrowings equal to $750.0 million , with the ability to further increase the borrowing capacity to $900.0 million , subject to lender approval. We can elect to have loans under our Credit Agreement bear interest either at a Eurodollar-based rate, plus a margin ranging from 2.00% to 3.25% 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 1.00% to 2.25% depending on the total leverage ratio then in effect. We also pay a commitment fee of 0.50% per annum on the undrawn portion of the revolving loan under the Credit Agreement. Our obligations under the Credit Agreement are secured by a lien on substantially all of our assets. Advances made under the Credit Agreement are guaranteed on a senior unsecured basis by certain of our subsidiaries (the “Guarantors”). These guarantees are full and unconditional and joint and several among the Guarantors. The terms of the Credit Agreement 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, which is September 5, 2019. The Credit Agreement contains certain financial covenants, including a consolidated total leverage ratio which requires our indebtedness not to exceed 4.75 times adjusted consolidated EBITDA for the prior twelve month period, adjusted in accordance with the Credit Agreement (except for the current and subsequent two quarters after the consummation of a permitted acquisition, at which time the covenant may be increased to 5.25 times adjusted consolidated EBITDA) and a minimum interest coverage ratio that requires our adjusted consolidated EBITDA to exceed consolidated interest charges by not less than 2.50 times. The financial covenants in our Credit Agreement may limit the amount available to us for borrowing to less than $750.0 million . In addition to the financial covenants described above, the Credit Agreement also contains customary events of default (including those relating to monetary defaults, covenant defaults, cross defaults and bankruptcy events). As of June 30, 2016, our consolidated total leverage ratio was 4.15 and our interest coverage ratio was 8.86 , which was in compliance with the related requirements. For the six months ended June 30, 2016 and 2015 , the weighted average interest rate on borrowings under our Credit Agreement was approximately 4.35% and 3.15% , respectively. At June 30, 2016 and December 31, 2015 , letters of credit outstanding under the Credit Agreement were $5.4 million and $1.8 million , respectively. As of June 30, 2016, we were in compliance with the covenants included in the Credit Agreement. Our ability to maintain compliance with the consolidated total leverage and interest coverage ratios included in the Credit Agreement may be subject to, among other things, the timing and success of initiatives we are pursuing, which may include expansion capital projects, acquisitions or drop down transactions, as well as the associated financing for such initiatives. Other debt Other debt represents insurance premium financing in the original amount of $3.0 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 2016.

Partners' Capital

Partners' Capital	6 Months Ended
	Jun. 30, 2016
Equity [Abstract]
Partners' Capital	Partners’ Capital and Convertible Preferred Units Our capital accounts are comprised of approximately 1.3% notional general partner interests and 98.7% limited partner interests as of June 30, 2016 . 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 incentive distribution rights that are non-voting limited partner interests held by our General Partner. Pursuant to our Partnership Agreement, our General Partner participates in losses and distributions based on its interest. The General Partner's participation in the allocation of losses and distributions is not limited and therefore, such participation can result in a deficit to its capital account. As such, allocation of losses and distributions, including distributions for previous transactions between entities under common control, has resulted in a deficit to the General Partner's capital account included in our condensed consolidated balance sheets. Affiliates of our General Partner hold and participate in distributions on our Series A Units and newly issued Series C Units (see below for further details) with such distributions being made in paid-in-kind units, cash or a combination thereof, at the election of the Board of Directors of our General Partner. The Series A Units and Series C Units are entitled to vote along with Limited Partner common unitholders and such units are currently convertible to common units. On February 1, 2016, all outstanding Series B Units were converted on a one-for-one basis into common units. Prior to their conversion, our General Partner held and participated in distributions on our Series B Units with such distributions being made in cash or with paid-in-kind Series B Units. The holders of Series B Units were entitled to vote along with the holders of common units prior to conversion. At-The-Market ("ATM") Offering On October 18, 2015, we filed a prospectus supplement related to the offer and sale from time to time of common units in an at-the-market offering. For the six months ended June 30, 2016, we sold 248,561 common units for proceeds of $3.2 million , net of commissions and accrued offering costs of less than $0.1 million , which were used for general partnership purposes including the repayment of amounts outstanding under the Credit Agreement, the funding of acquisitions and the funding of capital expenditures. As of June 30, 2016, approximately $96.8 million remained available for sale under the Partnership's ATM Equity Offering Sales Agreement. Series C Convertible Preferred Units On April 25, 2016, the Series C Convertible Preferred Units (the "Series C Units") were created and issued pursuant to the Fifth Amended and Restated Agreement of Limited Partnership of American Midstream Partners, LP ("Partnership Agreement"). The Series C Units have the right to receive cumulative distributions in the same priority as the Series A Units, which is before any other distributions made in respect of any other partnership interests, in the amounts described herein with such distributions being made in paid-in-kind units, cash or a combination thereof, at the election of the Board of Directors of our General Partner. If all or any portion of a distribution on the Series C Units is to be paid in cash, then the aggregate amount of such cash to be distributed in respect of the Series C Units outstanding will be paid out of available cash in the same priority as any cash distributions made to the Series A unitholders, which will be made prior to any distributions to the General Partner or our common unitholders. To the extent that any portion of a distribution on Series C units (or Series A units) to be paid in cash exceeds the amount of Available Cash (as defined in the Partnership Agreement), an amount of cash equal to the Available Cash will be paid pro rata to the Series A unitholders and the Series C unitholders and the balance of such Series A quarterly distribution and Series C quarterly distributions will become an arrearage until paid in a future quarter. The Series C 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 on an as converted basis, with each Series C Unit initially entitled to one vote for each common unit into which such Series C Unit is convertible. The Series C Units also have separate class voting rights on any matter, including a merger, consolidation or business combination, that adversely affects, amends or modifies any of the rights, preferences, privileges or terms of the Series C Units. The Series C Units are convertible in whole or in part into common units at any time. The number of common units into which a Series C Unit is convertible will be an amount equal to (i) the sum of $14.00 and all accrued and accumulated but unpaid distributions, divided by (ii) the conversion price. In the event that the Partnership issues, sells or grants any common units or convertible securities at an indicative per common unit price that is less than $14.00 per common unit (subject to customary anti-dilution adjustments), then the conversion will be adjusted according to a formula to provide for an increase in the number of common units into which Series C Units are convertible. 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 C 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 the $14.00 multiplied by the number of Series C Units owned by such holders, plus all accrued but unpaid distributions. Call Right At any time prior to April 25, 2017, the Partnership has the right (the “Series C Call Right”) to require the holders of the Series C Units to sell, assign and transfer all or a portion of the then outstanding Series C Units to the Partnership for a purchase price of $14.00 per Series C Unit (subject to customary anti-dilution adjustments), plus all accrued but unpaid distributions on each Series C Unit. The Partnership may not exercise the Series C Call Right with respect to any Series C Unit if the holder has elected to convert it into common units on or prior to the date the Partnership has provided notice of its intent to exercise its Series C Call Right, and may not exercise the Series C Call Right if doing so would violate applicable law or result in a default under any financing agreement or obligation of the Partnership or its affiliates. Warrant On April 25, 2016, pursuant to the Securities Purchase Agreement, the Partnership issued the Warrant to Magnolia Infrastructure Partners, LLC ("Magnolia," an affiliate of our General Partner), which allows it to purchase up to 800,000 common units at an exercise price of $7.25 per common unit. The Warrant is subject to standard anti-dilution adjustments and is exercisable for a period of seven years. On April 25, 2017, the number of common units that may be purchased pursuant to the exercise of the Warrant will be adjusted by an amount, rounded to the nearest whole common unit, equal to the product obtained by the following calculation: (i) 400,000 multiplied by (ii) (A) the Series C Issue Price multiplied by the number of Series C Units then outstanding less $45.0 million divided by (B) the Series C Issue Price multiplied by the number of Series C Units issued, less $45.0 million . Each issuance of any Series C Units issued in-kind as a distribution to holders of Series C Units ("Series C PIK Units") will increase the number of common units that can be purchased upon exercise of the Warrant by an amount, rounded to the nearest whole common unit, equal to the product obtained by the following calculation: (i) the total number of common units into which each Warrant may be exercised immediately prior to the most recent issuance of the Series C PIK Units multiplied by (ii) (A) the total number of outstanding Series C Units immediately after the most recent issuance of Series C PIK Units divided by (B) the total number of outstanding Series C Units immediately prior to the most recent issuance of Series C PIK Units. The fair value of the Warrant was determined using a market approach that utilized significant inputs which are not observable in the market and thus represent a Level 3 measurement as defined by ASC 820. The estimated fair value of $4.41 per warrant unit was determined using a Black-Scholes model and the following significant assumptions: i) a dividend yield of 18% , ii) common unit volatility of 42% and iii) the seven-year term of the warrant to arrive at an aggregate fair value of $4.5 million . General Partner Units In order to maintain its ownership percentage, we received proceeds of $1.8 million from our General Partner as consideration for the issuance of 128,272 additional notional general partner units for the six months ended June 30, 2016 . For the six months ended June 30, 2015 , we received proceeds of $0.3 million for the issuance of 18,706 additional notional general partner units. Outstanding Units The number of units outstanding as of June 30, 2016 and December 31, 2015 , respectively, were as follows (in thousands): June 30, December 31, Series A convertible preferred units 9,797 9,210 Series B convertible units — 1,350 Series C convertible preferred units 8,571 — Limited Partner common units 31,146 30,427 General Partner units 664 536 Distributions We made cash distributions as follows (in thousands): Three months ended June 30, Six months ended June 30, 2016 2015 2016 2015 Limited Partner common units $ 12,745 $ 10,753 $ 27,763 $ 21,466 General Partner units 173 159 395 317 General Partners' incentive distribution rights — 1,293 1,806 2,581 $ 12,918 $ 12,205 $ 29,964 $ 24,364 On July 21, 2016, the Board of Directors of our General Partner declared a quarterly cash distribution of $0.4125 per unit for the quarter ended June 30, 2016 , or $1.65 per unit on an annualized basis and equal to the Minimum Quarterly Distribution as defined in the Partnership Agreement. The distribution is expected to be paid on August 12, 2016, to unitholders of record as of the close of business on August 3, 2016. At June 30, 2016 , we had accrued contractual cash distributions of $2.4 million and $2.2 million of paid-in-kind Series A Units that will be issued in August 2016. At June 30, 2016 , we accrued contractual cash distributions of $1.3 million and $0.9 million of paid-in-kind Series C Units that will be issued in August 2016. For the six months ended June 30, 2016 , the Partnership issued 586,882 of paid-in-kind Series A Units and accrued a combination of cash and paid-in-kind unitholder distributions for Series A Units with a fair value of $9.1 million . For the six months ended June 30, 2015 , the Partnership issued 365,641 of paid-in-kind Series A Units and accrued a combination of cash and paid-in-kind unitholder distributions for Series A Units with a fair value of $7.6 million . The fair value of the paid-in-kind Series A and C Unit distributions for all quarters presented was determined primarily using the market and income approaches, requiring significant inputs which are not observable in the market and thus represent a Level 3 measurement as defined by ASC 820. Under the income approach, the fair value estimates for all periods presented were based on i) present value of estimated future contracted distributions, ii) option values ranging from $0.02 per unit to $1.88 per unit using a Black-Scholes model, and iii) assumed discount rates of 10.0% and 18.0% , respectively. Net Income (Loss) attributable to Limited Partners 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 Units and Series C Units, declared distributions on the Series B Units, General Partner units, including incentive distribution rights. 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 limited partners' net income (loss) per common unit. Basic and diluted limited partners' net income (loss) per common 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. We determined basic and diluted limited partners' net income (loss) per common unit as follows (in thousands, except per unit amounts): Three months ended June 30, Six months ended June 30, 2016 2015 2016 2015 Net income (loss) from continuing operations $ (3,591 ) $ (2,002 ) $ (7,555 ) $ (1,166 ) Less: Net income (loss) attributable to noncontrolling interests 992 32 979 46 Net income (loss) from continuing operations attributable to the Partnership (4,583 ) (2,034 ) (8,534 ) (1,212 ) Less: Distributions on Series A Units 4,602 4,196 9,073 7,607 Distributions on Series C Units 2,249 — 2,249 — Declared distributions on Series B Units — 413 — 833 General partner's distribution 173 1,452 2,201 2,899 General partner's share in undistributed loss (322 ) (234 ) (659 ) (422 ) Net income (loss) from continuing operations available to Limited Partners (11,285 ) (7,861 ) (21,398 ) (12,129 ) Net income (loss) from discontinued operations available to Limited Partners — (31 ) — (26 ) Net income (loss) available to Limited Partners $ (11,285 ) $ (7,892 ) $ (21,398 ) $ (12,155 ) Weighted average number of common units used in computation of Limited Partners’ net income (loss) per common unit (basic and diluted) 30,949 22,757 30,884 22,730 Limited Partners' net income (loss) per common unit (basic and diluted) $ (0.36 ) $ (0.35 ) $ (0.69 ) $ (0.53 )

Long-Term Incentive Plan

Long-Term Incentive Plan	6 Months Ended
	Jun. 30, 2016
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 19, 2015, the Board of Directors of our General Partner approved the Third Amended and Restated Long-Term Incentive Plan to increase the number of common units authorized for issuance by 6,000,000 common units. On February 11, 2016, the unitholders approved the Third Amended and Restated Long-Term Incentive Plan (as amended and as currently in effect as of the date hereof, the "LTIP") which, among other things, increased the number of available awards by 6,000,000 common units. At June 30, 2016 and December 31, 2015 , there were 4,941,325 and 15,484 common unit, respectively, available for future issuance under the LTIP. All such equity-based awards issued under the LTIP consist of phantom units, Distribution Equivalent Rights ("DERs") or Option Grants. DERs and options have been granted on a limited basis. Future awards, such as options and DERs, may be granted at the discretion of the Compensation Committee and subject to approval by the Board of Directors of our General Partner. Phantom Unit Awards. Ownership in the phantom unit awards is subject to forfeiture until the vesting date. The LTIP is administered by the Compensation Committee of the Board of Directors of our General Partner, which at its discretion, may elect to settle such vested phantom units with a number of common 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. Under the LTIP, grants issued typically vest in increments of 25% on each grant anniversary date and do not contain any vesting requirements other than continued employment. In December 2015, the Board of Directors of our General Partner approved a grant of 200,000 phantom units under the LTIP which contains DERs based on the extent to which the Partnership’s Series A Unitholders receive distributions in cash and will vest in one lump sum installment on the three year anniversary of the date of grant, subject to acceleration in certain circumstances. The following table summarizes activity in our phantom unit-based awards for the six months ended June 30, 2016 : Units Weighted-Average Grant Price Outstanding at beginning of period 569,759 $ 13.15 Granted 1,177,509 1.05 Forfeited (102,934 ) 5.36 Vested (179,326 ) 11.75 Outstanding at end of period 1,465,008 $ 4.14 The fair value of our phantom units, which are subject to equity classification, is based on the fair value of our common units at the grant date. Compensation costs related to these awards, including amortization applicable to prior awards, for the three months ended June 30, 2016 and 2015 were $1.0 million and $0.6 million , respectively, and for the six months ended June 30, 2016 and 2015 , were $2.1 million and $ 2.2 million , respectively, which are classified as Equity compensation expense in our condensed consolidated statements of operations and in partners’ capital on our condensed consolidated balance sheets. The total fair value of vested units at the time of vesting was $1.0 million and $2.3 million for the six months ended June 30, 2016 and 2015 , respectively. Equity compensation expense related to unvested awards not yet recognized at June 30, 2016 and 2015 was $5.0 million and $6.0 million , respectively, and the weighted average period over which this cost is expected to be recognized as of June 30, 2016 was approximately 2.4 years . Performance and Service Condition Awards. In November 2015, the Board of Directors of our General Partner modified awards to introduce certain performance and service conditions that we believe are probable of being achieved, amounting to $2.0 million payable in a variable amount of phantom units awards at the time of grant. These awards are accounted for as liability-based awards and equity-based compensation is to be accrued from the service-inception date through the estimated date of meeting both the performance and service conditions. Compensation costs related to these awards for the three and six months ended June 30, 2016 was $0.4 million and $0.6 million , respectively. Compensation costs related to unvested awards not yet recognized at June 30, 2016 was $0.9 million . Option to Purchase Common Units. In December 2015, the Board of Directors of our General Partner approved the grant of an option to purchase 200,000 common units of the Partnership at an exercise price per unit equal to $7.50 (the “Option Grant”). The Option Grant will vest in one lump sum installment on January 1, 2019, subject to acceleration in certain circumstances, and will expire on March 15th of the calendar year following the calendar year in which it vests. The following table summarizes our Option Grant awards, in units: Six months ended June 30, 2016 Units Weighted-Average Exercise Price Outstanding at beginning of period 200,000 $ 7.50 Granted — — Forfeited — — Vested — — Outstanding at end of period 200,000 $ 7.50 Compensation costs related to these awards for the three and six months ended June 30, 2016 was immaterial. Compensation costs related to unvested awards not yet recognized at June 30, 2016 was $0.1 million .

Income Tax (Notes)

Income Tax (Notes)	6 Months Ended
	Jun. 30, 2016
Income Tax Disclosure [Abstract]
Income Tax	Income Taxes With the exception of certain subsidiaries in our Terminals Segment, the Partnership is not subject to U.S. federal or state income taxes as such income taxes are generally borne by our unitholders through the allocation of our taxable income (loss) to them. The State of Texas does impose a franchise tax that is assessed on the portion of our taxable margin that is apportioned to Texas. Income tax expense for the three and six months ended June 30, 2016 was $0.5 million and $ 0.9 million , respectively, resulting in an effective tax rate of 17.7% and 12.8% , respectively. For the three and six months ended June 30, 2015 , income tax expense was $0.3 million and $ 0.5 million , respectively, resulting in an effective tax rate of 18.8% and 68.3% , respectively. The effective tax rates for the three and six months ended June 30, 2016 and 2015 , differ from the statutory rate primarily due to the portion of the Partnership's income and loss that is not subject to U. S. federal and state income taxes, as well as transactions between the Partnership and its taxable subsidiary that generate tax deductions for the taxable subsidiary, which are eliminated in consolidation

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Legal proceedings We are not currently party to any pending litigation or governmental proceedings, other than ordinary routine litigation incidental to our business. While the ultimate impact of any proceedings cannot be predicted with certainty, our management believes that the resolution of any of our pending proceedings will not have a material adverse effect on our financial condition or results of operations. 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 pipelines, 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. Regulatory matters On October 8, 2014, Midla reached an agreement in principle with its customers regarding the interstate pipeline that traverses Louisiana and Mississippi in order to provide continued service to its customers while addressing safety concerns with the existing pipeline. On April 16, 2015, the FERC approved the stipulation and agreement (the "Midla Agreement") allowing Midla to retire the existing 1920s vintage pipeline and replace it with a new pipeline from Winnsboro, Louisiana to Natchez, Mississippi (the “Midla-Natchez Line”) to serve existing residential, commercial, and industrial customers. Under the Midla Agreement, customers not served by the new Midla-Natchez Line will be connected to other interstate or intrastate pipelines, other gas distribution systems, or offered conversion to propane service. On June 29, 2015, the Partnership filed with the FERC for authorization to construct the Midla-Natchez pipeline, which was approved on December 17, 2015. Construction commenced in the second quarter of 2016 with service expected to begin in early 2017. Under the Midla Agreement, Midla plans to execute long-term agreements seeking to recover its investment in the Midla-Natchez Line. Exit and disposal costs On March 9, 2016, management committed and communicated to its employees a corporate relocation plan. The plan includes relocation assistance or one-time termination benefits for employees who render service until their respective termination date. Charges associated with one-time termination benefits will be recognized ratably over the requisite service period and presented in Selling, general and administrative expenses . We have estimated the fair value of the initial charge to be approximately $3.6 million , of which $2.5 million has been recorded in Accrued expenses and other current liabilities as of June 30, 2016. We expect the plan to be complete by the fourth quarter of 2016. As part of the corporate relocation plan we have executed a 16-year office sublease as of June 29, 2016 with an estimated operating lease commitment of approximately $15.9 million .

Related-Party Transactions

Related-Party Transactions	6 Months Ended
	Jun. 30, 2016
Related Party Transactions [Abstract]
Related-Party Transactions	Related-Party Transactions Employees of our General Partner are assigned to work for the Partnership or other affiliates of our General Partner. 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 or affiliate. Our General Partner does not record any profit or margin for the administrative and operational services charged to us. During the three and six months ended June 30, 2016 , administrative payroll and operational services expenses of $8.9 million and $ 16.9 million , respectively, were charged to the Partnership by our General Partner. During the three and six months ended June 30, 2015 , administrative payroll and operational services expenses of $ 6.9 million and $ 14.2 million , respectively, were charged to the Partnership by our General Partner. For the three and six months ended June 30, 2016 , our General Partner incurred approximately $0.1 million and $ 0.4 million , respectively, of business development expenses that were funded by the Partnership. For the three and six months ended June 30, 2015 , our General Partner incurred approximately $ 0.5 million and $0.9 million of such costs. 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 related costs and record those costs in our consolidated statements of operations. During the second quarter of 2014, the Partnership and an affiliate of its General Partner entered into a Management Service Fee arrangement under which the affiliate pays a monthly fee to reimburse the Partnership for administrative expenses incurred on the affiliate's behalf. For the three and six months ended June 30, 2016 , the Partnership recognized $0.2 million and $ 0.4 million , respectively, in management fee income, and recognized $ 0.4 million and $0.9 million , respectively, for the three and six months ended June 30, 2015 that was recorded as a reduction to Selling, general and administrative expenses . For the three and six months ended June 30, 2016 , an affiliate of our General Partner also incurred approximately $0.3 million and $ 0.2 million , respectively, of costs associated with reimbursable costs incurred on behalf of these affiliates. For the three and six months ended June 30, 2015 , an affiliate of our General Partner also incurred approximately $ 0.5 million and $0.9 million , respectively, of costs associated with reimbursable costs incurred on behalf of these affiliates. As of June 30, 2016 and December 31, 2015 , the Partnership had $2.4 million and $3.8 million , respectively, due to our General Partner, which has been recorded in Accrued expenses and other current liabilities and relates primarily to compensation. This payable is generally settled on a quarterly basis related to the foregoing transactions.

Reporting Segments

Reporting Segments	6 Months Ended
	Jun. 30, 2016
Segment Reporting [Abstract]
Reporting Segments	Reportable Segments Our operations are located in the United States and are organized into three reportable 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 crude oil, which include transporting raw natural gas and crude oil from various receipt points through gathering systems, treating the raw natural gas, processing raw natural gas to separate the NGLs from the natural gas, fractionating NGLs, and selling or delivering pipeline-quality natural gas, crude oil 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 ("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 petroleum products, distillates, chemicals and agricultural products. These segments are monitored separately by management for performance and are consistent with the Partnership's 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 results of each segment. The following tables set forth our segment information for the three and six months ended June 30, 2016 and 2015 (in thousands): Three months ended June 30, 2016 Gathering and Processing Transmission Terminals Total Revenue $ 41,780 $ 8,740 $ 5,628 $ 56,148 Gain (loss) on commodity derivatives, net (764 ) (2 ) — (766 ) Total revenue 41,016 8,738 5,628 55,382 Operating expenses: Purchases of natural gas, NGL's and condensate 20,964 1,138 — 22,102 Direct operating expenses 11,231 3,425 1,535 16,191 Selling, general and administrative expenses 11,432 Equity compensation expense 1,025 Depreciation, amortization and accretion expense 10,903 Total operating expenses 61,653 Gain (loss) on sale of assets, net 80 Interest expense (8,507 ) Earnings in unconsolidated affiliates 11,647 Income tax (expense) benefit (540 ) Net income (loss) (3,591 ) Less: Net income (loss) attributable to noncontrolling interests 992 Net income (loss) attributable to the Partnership $ (4,583 ) Segment gross margin (a) $ 20,605 $ 7,593 $ 4,093 $ 32,291 (a) Segment gross margin for our Gathering and Processing segment consists of total revenue plus unrealized losses on commodity derivatives of $0.5 million and loss on construction and operating management agreement ("COMA") of less than $0.1 million , less purchases of natural gas, NGLs and condensate. Segment gross margin for our Transmission segment consists of total revenue less COMA income of less than $0.1 million and purchases of natural gas, NGLs and condensate. Segment gross margin for our Terminals segment consists of total revenue less direct operating expenses. Three months ended June 30, 2015 Gathering and Processing Transmission Terminals Total Revenue $ 50,439 $ 12,423 $ 4,336 $ 67,198 Gain (loss) on commodity derivatives, net 311 — — 311 Total revenue 50,750 12,423 4,336 67,509 Operating expenses: Purchases of natural gas, NGL's and condensate 30,272 3,062 — 33,334 Direct operating expenses 9,130 3,253 1,584 13,967 Selling, general and administrative expenses 5,571 Equity compensation expense 550 Depreciation, amortization and accretion expense 9,250 Total operating expenses 62,672 Gain (loss) on sale of assets, net (2,970 ) Interest expense (3,556 ) Earnings in unconsolidated affiliate 4 Income tax (expense) benefit (317 ) Income (loss) from discontinued operations, net of tax (31 ) Net income (loss) (2,033 ) Less: Net income (loss) attributable to noncontrolling interests 32 Net income (loss) attributable to the Partnership $ (2,065 ) Segment gross margin (a) $ 20,219 $ 9,333 $ 2,752 $ 32,304 (a) Segment gross margin for our Gathering and Processing segment consists of total revenue less (i) unrealized gains on commodity derivatives of $0.1 million , (ii) COMA income of $0.2 million and (iii) purchases of natural gas, NGLs and condensate. (b) Segment gross margin for our Transmission segment consists of total revenue less COMA income of less than $0.1 million and purchases of natural gas, NGLs and condensate. Segment gross margin for our Terminals segment consists of total revenue less direct operating expenses. Six months ended June 30, 2016 Gathering and Processing Transmission Terminals Total Revenue $ 72,928 $ 18,967 $ 10,376 $ 102,271 Gain (loss) on commodity derivatives, net (867 ) (2 ) — (869 ) Total revenue 72,061 18,965 10,376 101,402 Operating expenses: Purchases of natural gas, NGL's and condensate 36,412 2,602 — 39,014 Direct operating expenses 21,234 6,266 3,212 30,712 Selling, general and administrative expenses 19,966 Equity compensation expense 2,109 Depreciation, amortization and accretion expense 20,997 Total operating expenses 112,798 Gain (loss) on sale of assets, net 90 Interest expense (14,379 ) Earnings in unconsolidated affiliates 18,990 Income tax (expense) benefit (860 ) Net income (loss) (7,555 ) Less: Net income (loss) attributable to noncontrolling interests 979 Net income (loss) attributable to the Partnership $ (8,534 ) Segment gross margin (a) $ 36,336 $ 16,348 $ 7,164 $ 59,848 (a) Segment gross margin for our Gathering and Processing segment consists of total revenue plus unrealized losses on commodity derivatives of $0.6 million and loss on COMA of $0.1 million , less purchases of natural gas, NGLs and condensate. (b) Segment gross margin for our Transmission segment consists of total revenue less COMA income of less than $0.1 million and purchases of natural gas, NGLs and condensate. Segment gross margin for our Terminals segment consists of total revenue less direct operating expenses. Six months ended June 30, 2015 Gathering and Processing Transmission Terminals Total Revenue $ 98,888 $ 24,171 $ 8,601 $ 131,660 Gain (loss) on commodity derivatives, net 458 — — 458 Total revenue 99,346 24,171 8,601 132,118 Operating expenses: Purchases of natural gas, NGL's and condensate 57,590 4,721 — 62,311 Direct operating expenses 18,223 6,432 3,179 27,834 Selling, general and administrative expenses 12,506 Equity compensation expense 2,248 Depreciation, amortization and accretion expense 18,939 Total operating expenses 123,838 Gain (loss) on sale of assets, net (2,978 ) Interest expense (6,166 ) Earnings in unconsolidated affiliates 171 Income tax (expense) benefit (473 ) Income (loss) from discontinued operations, net of tax (26 ) Net income (loss) (1,192 ) Less: Net income (loss) attributable to noncontrolling interests 46 Net income (loss) attributable to the Partnership $ (1,238 ) Segment gross margin (a) $ 41,265 $ 19,394 $ 5,422 $ 66,081 (a) Segment gross margin for our Gathering and Processing segment consists of total revenue less (i) unrealized gains on commodity derivatives of $0.1 million , (ii) COMA income of $0.4 million and (iii) purchases of natural gas, NGLs and condensate. Segment gross margin for our Transmission segment consists of total revenue less COMA income of $0.1 million and purchases of natural gas, NGLs and condensate. Segment gross margin for our Terminals segment consists of total revenue less direct operating expenses. A reconciliation of total assets by segment to the amounts included in the condensed consolidated balance sheets follows: June 30, December 31, 2016 2015 Segment assets: Gathering and Processing $ 586,782 $ 572,824 Transmission 151,518 133,870 Terminals 94,790 84,449 Other (a) 317,878 100,153 Total assets $ 1,150,968 $ 891,296 (a) Other assets not allocable to segments consist of investment in unconsolidated affiliates, corporate leasehold improvements and other assets.

Organization and Basis of Pre26

Organization and Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Business	Nature of Business We are engaged in the business of gathering, treating, processing and transporting natural gas; gathering, transporting, storing, treating and fractionating NGLs; gathering, storing and transporting crude oil and condensates; and storing specialty chemical products, all through our ownership and operation of 13 gathering systems, five processing facilities, three fractionation facilities, three interstate pipelines, five intrastate pipelines, three marine terminal sites and one crude oil pipeline. Our primary assets, which are strategically located in Alabama, Georgia, Louisiana, Mississippi, North Dakota, Tennessee, Texas and the Gulf of Mexico, provide critical infrastructure that links producers of natural gas, crude oil, NGLs, condensate and specialty chemicals to numerous intermediate and end-use markets. We currently operate more than 3,000 miles of pipelines that gather and transport over 1 Bcf/d of natural gas and operate approximately 2.2 million barrels of storage capacity across three marine terminal sites.
Basis of Presentation	Basis of Presentation These unaudited condensed consolidated financial statements have been prepared in accordance with GAAP for interim financial information. Accordingly, they do not include all of the information and footnotes required by GAAP for annual financial statements. The year-end balance sheet data was derived from consolidated audited financial statements but does not include disclosures required by GAAP for annual periods. The information furnished herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for a fair statement of financial position and results of operations for the respective interim periods. Our financial results for the three and six months ended June 30, 2016 , are not necessarily indicative of the results that may be expected for the year ending December 31, 2016 . These unaudited condensed consolidated financial statements should be read in conjunction with our consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2015 , filed with the Securities and Exchange Commission (the "SEC") on March 7, 2016 (“Annual Report”)
Consolidation Policy	Consolidation Policy The accompanying condensed consolidated financial statements include the 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 condensed consolidated financial statements.
Equity Method Investments	Investment in Unconsolidated Affiliates We hold various non-operated membership interests in entities that own and operate natural gas pipeline systems, NGL and crude oil pipelines in and around Louisiana, Alabama, Mississippi and the Gulf of Mexico. These non-operated membership interests in which the Partnership exercises significant influence, but does not control and is not the primary beneficiary, are accounted for using the equity method and are reported in Investment in unconsolidated affiliates in the accompanying condensed consolidated balance sheets. The Partnership believes the equity method is an appropriate means to recognize increases or decreases, measured by GAAP, in the economic resources underlying the investments. Regular evaluation of these investments is appropriate to evaluate any potential need for impairment. The Partnership uses evidence of a loss in value to identify if an investment has incurred an other than temporary decline.
Use of Estimates	Use of Estimates When preparing condensed consolidated 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 assumptions are based on information available at the time such estimates and assumptions are made. Adjustments made with respect to the use of these estimates and assumptions often relate to information not previously available. Uncertainties with respect to such estimates and assumptions are inherent in the preparation of financial statements. Estimates and assumptions 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.

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	6 Months Ended
	Jun. 30, 2016
Business Combinations [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following tables summarize the fair value of consideration transferred by the Partnership for the acquisition and the preliminary allocation of that amount to the assets acquired and liabilities assumed based on their respective fair values as of the acquisition date (in thousands). Fair value of consideration transferred: Cash $ 3,073 Fair value of assets acquired, liabilities assumed: Assets: Property, plant and equipment: Pipelines $ 16,952 Land 421 Total property, plant and equipment 17,373 Liabilities: Asset retirement obligations (14,300 ) Fair value of net assets acquired and liabilities assumed $ 3,073

Other Current Assets (Tables)

Other Current Assets (Tables)	6 Months Ended
	Jun. 30, 2016
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Other Current Assets	Other current assets consisted of the following (in thousands): June 30, December 31, 2016 2015 Prepaid insurance $ 3,073 $ 3,948 Accrued distributions from unconsolidated affiliates 4,359 — Other prepaid amounts 2,108 2,866 Other current assets 3,808 3,280 $ 13,348 $ 10,094

Derivatives (Tables)

Derivatives (Tables)	6 Months Ended
	Jun. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Fair value associated with commodity derivative instruments	As of June 30, 2016 and December 31, 2015 , the value associated with our commodity derivatives, interest rate swaps, and weather derivative were recorded in our condensed consolidated balance sheets as follows (in thousands): Gross Risk Management Assets Gross Risk Management (Liabilities) Net Risk Management Assets (Liabilities) Balance Sheet Classification June 30, December 31, 2015 June 30, December 31, 2015 June 30, December 31, 2015 Current $ 944 $ 365 $ — $ — $ 944 $ 365 Noncurrent — — — — — — Total assets $ 944 $ 365 $ — $ — $ 944 $ 365 Current $ — $ — $ (832 ) $ — $ (832 ) $ — Noncurrent — — (2,556 ) — (2,556 ) — Total liabilities $ — $ — $ (3,388 ) $ — $ (3,388 ) $ —
Realized and unrealized gains (losses) with commodity and interst rate derivative instruments	For the three and six months ended June 30, 2016 and 2015 , respectively, the realized and unrealized gains (losses) associated with our commodity derivatives, interest rate swaps and weather derivative were recorded in our condensed consolidated statements of operations as follows (in thousands): Three months ended June 30, Six months ended June 30, Gain (loss) on Derivatives Gain (loss) on derivatives Statement of Operations Classification Realized Unrealized Realized Unrealized 2016 Gain (loss) on commodity derivatives, net $ (244 ) $ (522 ) $ (244 ) $ (625 ) Interest expense — (2,033 ) — (2,763 ) Direct operating expenses (232 ) — (450 ) — Total $ (476 ) $ (2,555 ) $ (694 ) $ (3,388 ) 2015 Gain (loss) on commodity derivatives, net $ 252 $ 59 $ 391 $ 67 Interest expense (101 ) 98 (203 ) 146 Direct operating expenses (234 ) — (475 ) — Total $ (83 ) $ 157 $ (287 ) $ 213

Fair Value Measurement (Tables)

Fair Value Measurement (Tables)	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Fair value of financial instruments	The following table sets forth, by level within the fair value hierarchy, our commodity derivative instruments and interest rate swaps, included as part of Risk management assets and Risk management liabilities within our condensed consolidated balance sheets, that were measured at fair value on a recurring basis as of June 30, 2016 and December 31, 2015 (in thousands): Carrying Amount Estimated Fair Value of the Assets (Liabilities) Level 1 Level 2 Level 3 Total Commodity derivative instruments, net: June 30, 2016 $ (625 ) $ — $ (625 ) $ — $ (625 ) December 31, 2015 — — — — — Interest rate swaps: June 30, 2016 $ (2,763 ) $ — $ (2,763 ) $ — $ (2,763 ) December 31, 2015 — — — — —

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	6 Months Ended
	Jun. 30, 2016
Property, Plant and Equipment [Abstract]
Property, plant and equipment, net	Property, plant and equipment, net, as of June 30, 2016 and December 31, 2015 were as follows (in thousands): Useful Life (in years) June 30, December 31, Land N/A $ 5,703 $ 5,282 Construction in progress N/A 61,203 46,045 Buildings and improvements 4 to 40 9,959 9,864 Processing and treating plants 8 to 40 102,003 97,784 Pipelines and compressors 3 to 40 573,084 554,400 Storage 20 to 40 58,226 58,394 Equipment 5 to 20 37,065 22,207 Total property, plant and equipment 847,243 793,976 Accumulated depreciation (164,134 ) (145,963 ) Property, plant and equipment, net $ 683,109 $ 648,013

Goodwill and Intangible Asset32

Goodwill and Intangible Assets, Net (Tables)	6 Months Ended
	Jun. 30, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Finite-Lived Intangible Assets	Intangible assets, net, consist of the following (in thousands): June 30, December 31, 2016 2015 Gross carrying amount: Customer relationships $ 53,400 $ 53,400 Dedicated acreage 53,350 53,350 $ 106,750 $ 106,750 Accumulated amortization: Customer relationships $ (4,410 ) $ (3,124 ) Dedicated acreage (3,550 ) (2,661 ) $ (7,960 ) $ (5,785 ) Net carrying amount: Customer relationships $ 48,990 $ 50,276 Dedicated acreage 49,800 50,689 $ 98,790 $ 100,965

Investment in unconsolidated 33

Investment in unconsolidated affiliates (Tables)	6 Months Ended
	Jun. 30, 2016
Schedule of Equity Method Investments [Line Items]
Investments in and Advances to Affiliates	The following table presents the activity in the Partnership's equity investments for the six months ended June 30, 2016 (in thousands): Destin Tri-States Delta House Others (1) Total Balances at December 31, 2015 $ — $ — $ 56,525 $ 25,776 $ 82,301 Investments 122,830 56,681 9,873 32,515 221,899 Earnings in unconsolidated affiliates 2,027 869 14,264 1,830 18,990 Contributions — — — 12,459 12,459 Distributions (6,631 ) (1,092 ) (28,359 ) (3,995 ) (40,077 ) Balances at June 30, 2016 $ 118,226 $ 56,458 $ 52,303 $ 68,585 $ 295,572
Equity Method Investments	The following table summarizes our percentage ownership interests in investments in unconsolidated affiliates: Percentage Ownership Destin 49.7 % Tri-States 16.7 % Delta House 13.9 % Wilprise 25.3 % Okeanos 66.7 % Main Pass Oil Gathering Company, LLC ("MPOG") 66.7 % Mesquite 47.3 % The following tables present the summarized combined financial information for the Partnership's equity investments (amounts represent 100% of investee financial information): Balance Sheets: June 30, 2016 December 31, 2015 Current assets $ 170,283 $ 2,086 Non-current assets 1,470,286 288,617 Current liabilities 182,895 366 Non-current liabilities 475,602 23,617 Three months ended June 30, Six months ended June 30, Income Statements: 2016 2015 2016 2015 Total revenue $ 87,054 $ 1,974 $ 151,997 $ 4,410 Operating expense 6,649 768 7,541 1,738 Net income 65,613 (2 ) 120,777 241

Accrued Expenses and Other Cu34

Accrued Expenses and Other Current Liabilities (Tables)	6 Months Ended
	Jun. 30, 2016
Other Liabilities Disclosure [Abstract]
Schedule of Accrued Liabilities	Accrued expenses and other current liabilities were as follows (in thousands): June 30, December 31, 2016 2015 Current portion of asset retirement obligation (a) $ 6,826 $ 6,822 Accrued capital expenditures 8,299 3,984 Accrued expenses 11,788 3,178 Due to related parties 2,424 3,894 Other 7,740 7,157 $ 37,077 $ 25,035 (a) Associated with certain Gathering and Processing assets.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2016
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	The following table is a reconciliation of the asset retirement obligations for the six months ended June 30, 2016 (in thousands): Beginning asset retirement obligation $ 35,371 Liabilities assumed 14,300 Expenditures (11 ) Accretion expense 596 Total ending asset retirement obligation $ 50,256 Less: current portion 6,826 Long-term asset retirement obligation $ 43,430

Debt Obligations (Tables)

Debt Obligations (Tables)	6 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Outstanding borrowings under the credit facility	Our outstanding borrowings under the credit facility were (in thousands): June 30, December 31, Revolving credit facility $ 672,400 $ 525,100 Other debt 731 2,338 Total debt 673,131 527,438 Less: current portion 731 2,338 Long-term debt $ 672,400 $ 525,100

Partners' Capital (Tables)

Partners' Capital (Tables)	6 Months Ended
	Jun. 30, 2016
Equity [Abstract]
Numbers of units outstanding	Distributions We made cash distributions as follows (in thousands): Three months ended June 30, Six months ended June 30, 2016 2015 2016 2015 Limited Partner common units $ 12,745 $ 10,753 $ 27,763 $ 21,466 General Partner units 173 159 395 317 General Partners' incentive distribution rights — 1,293 1,806 2,581 $ 12,918 $ 12,205 $ 29,964 $ 24,364 The number of units outstanding as of June 30, 2016 and December 31, 2015 , respectively, were as follows (in thousands): June 30, December 31, Series A convertible preferred units 9,797 9,210 Series B convertible units — 1,350 Series C convertible preferred units 8,571 — Limited Partner common units 31,146 30,427 General Partner units 664 536
Schedule of Calulation for Net Income (Loss) Per Limited Partner Unit	We determined basic and diluted limited partners' net income (loss) per common unit as follows (in thousands, except per unit amounts): Three months ended June 30, Six months ended June 30, 2016 2015 2016 2015 Net income (loss) from continuing operations $ (3,591 ) $ (2,002 ) $ (7,555 ) $ (1,166 ) Less: Net income (loss) attributable to noncontrolling interests 992 32 979 46 Net income (loss) from continuing operations attributable to the Partnership (4,583 ) (2,034 ) (8,534 ) (1,212 ) Less: Distributions on Series A Units 4,602 4,196 9,073 7,607 Distributions on Series C Units 2,249 — 2,249 — Declared distributions on Series B Units — 413 — 833 General partner's distribution 173 1,452 2,201 2,899 General partner's share in undistributed loss (322 ) (234 ) (659 ) (422 ) Net income (loss) from continuing operations available to Limited Partners (11,285 ) (7,861 ) (21,398 ) (12,129 ) Net income (loss) from discontinued operations available to Limited Partners — (31 ) — (26 ) Net income (loss) available to Limited Partners $ (11,285 ) $ (7,892 ) $ (21,398 ) $ (12,155 ) Weighted average number of common units used in computation of Limited Partners’ net income (loss) per common unit (basic and diluted) 30,949 22,757 30,884 22,730 Limited Partners' net income (loss) per common unit (basic and diluted) $ (0.36 ) $ (0.35 ) $ (0.69 ) $ (0.53 )

Long-Term Incentive Plan (Table

Long-Term Incentive Plan (Tables)	6 Months Ended
	Jun. 30, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Table summarizes our unit-based awards	The following table summarizes activity in our phantom unit-based awards for the six months ended June 30, 2016 : Units Weighted-Average Grant Price Outstanding at beginning of period 569,759 $ 13.15 Granted 1,177,509 1.05 Forfeited (102,934 ) 5.36 Vested (179,326 ) 11.75 Outstanding at end of period 1,465,008 $ 4.14
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value [Table Text Block]	The following table summarizes our Option Grant awards, in units: Six months ended June 30, 2016 Units Weighted-Average Exercise Price Outstanding at beginning of period 200,000 $ 7.50 Granted — — Forfeited — — Vested — — Outstanding at end of period 200,000 $ 7.50

Reporting Segments (Tables)

Reporting Segments (Tables)	6 Months Ended
	Jun. 30, 2016
Segment Reporting [Abstract]
Segment information	The following tables set forth our segment information for the three and six months ended June 30, 2016 and 2015 (in thousands): Three months ended June 30, 2016 Gathering and Processing Transmission Terminals Total Revenue $ 41,780 $ 8,740 $ 5,628 $ 56,148 Gain (loss) on commodity derivatives, net (764 ) (2 ) — (766 ) Total revenue 41,016 8,738 5,628 55,382 Operating expenses: Purchases of natural gas, NGL's and condensate 20,964 1,138 — 22,102 Direct operating expenses 11,231 3,425 1,535 16,191 Selling, general and administrative expenses 11,432 Equity compensation expense 1,025 Depreciation, amortization and accretion expense 10,903 Total operating expenses 61,653 Gain (loss) on sale of assets, net 80 Interest expense (8,507 ) Earnings in unconsolidated affiliates 11,647 Income tax (expense) benefit (540 ) Net income (loss) (3,591 ) Less: Net income (loss) attributable to noncontrolling interests 992 Net income (loss) attributable to the Partnership $ (4,583 ) Segment gross margin (a) $ 20,605 $ 7,593 $ 4,093 $ 32,291 (a) Segment gross margin for our Gathering and Processing segment consists of total revenue plus unrealized losses on commodity derivatives of $0.5 million and loss on construction and operating management agreement ("COMA") of less than $0.1 million , less purchases of natural gas, NGLs and condensate. Segment gross margin for our Transmission segment consists of total revenue less COMA income of less than $0.1 million and purchases of natural gas, NGLs and condensate. Segment gross margin for our Terminals segment consists of total revenue less direct operating expenses. Three months ended June 30, 2015 Gathering and Processing Transmission Terminals Total Revenue $ 50,439 $ 12,423 $ 4,336 $ 67,198 Gain (loss) on commodity derivatives, net 311 — — 311 Total revenue 50,750 12,423 4,336 67,509 Operating expenses: Purchases of natural gas, NGL's and condensate 30,272 3,062 — 33,334 Direct operating expenses 9,130 3,253 1,584 13,967 Selling, general and administrative expenses 5,571 Equity compensation expense 550 Depreciation, amortization and accretion expense 9,250 Total operating expenses 62,672 Gain (loss) on sale of assets, net (2,970 ) Interest expense (3,556 ) Earnings in unconsolidated affiliate 4 Income tax (expense) benefit (317 ) Income (loss) from discontinued operations, net of tax (31 ) Net income (loss) (2,033 ) Less: Net income (loss) attributable to noncontrolling interests 32 Net income (loss) attributable to the Partnership $ (2,065 ) Segment gross margin (a) $ 20,219 $ 9,333 $ 2,752 $ 32,304 (a) Segment gross margin for our Gathering and Processing segment consists of total revenue less (i) unrealized gains on commodity derivatives of $0.1 million , (ii) COMA income of $0.2 million and (iii) purchases of natural gas, NGLs and condensate. (b) Segment gross margin for our Transmission segment consists of total revenue less COMA income of less than $0.1 million and purchases of natural gas, NGLs and condensate. Segment gross margin for our Terminals segment consists of total revenue less direct operating expenses. Six months ended June 30, 2016 Gathering and Processing Transmission Terminals Total Revenue $ 72,928 $ 18,967 $ 10,376 $ 102,271 Gain (loss) on commodity derivatives, net (867 ) (2 ) — (869 ) Total revenue 72,061 18,965 10,376 101,402 Operating expenses: Purchases of natural gas, NGL's and condensate 36,412 2,602 — 39,014 Direct operating expenses 21,234 6,266 3,212 30,712 Selling, general and administrative expenses 19,966 Equity compensation expense 2,109 Depreciation, amortization and accretion expense 20,997 Total operating expenses 112,798 Gain (loss) on sale of assets, net 90 Interest expense (14,379 ) Earnings in unconsolidated affiliates 18,990 Income tax (expense) benefit (860 ) Net income (loss) (7,555 ) Less: Net income (loss) attributable to noncontrolling interests 979 Net income (loss) attributable to the Partnership $ (8,534 ) Segment gross margin (a) $ 36,336 $ 16,348 $ 7,164 $ 59,848 (a) Segment gross margin for our Gathering and Processing segment consists of total revenue plus unrealized losses on commodity derivatives of $0.6 million and loss on COMA of $0.1 million , less purchases of natural gas, NGLs and condensate. (b) Segment gross margin for our Transmission segment consists of total revenue less COMA income of less than $0.1 million and purchases of natural gas, NGLs and condensate. Segment gross margin for our Terminals segment consists of total revenue less direct operating expenses. Six months ended June 30, 2015 Gathering and Processing Transmission Terminals Total Revenue $ 98,888 $ 24,171 $ 8,601 $ 131,660 Gain (loss) on commodity derivatives, net 458 — — 458 Total revenue 99,346 24,171 8,601 132,118 Operating expenses: Purchases of natural gas, NGL's and condensate 57,590 4,721 — 62,311 Direct operating expenses 18,223 6,432 3,179 27,834 Selling, general and administrative expenses 12,506 Equity compensation expense 2,248 Depreciation, amortization and accretion expense 18,939 Total operating expenses 123,838 Gain (loss) on sale of assets, net (2,978 ) Interest expense (6,166 ) Earnings in unconsolidated affiliates 171 Income tax (expense) benefit (473 ) Income (loss) from discontinued operations, net of tax (26 ) Net income (loss) (1,192 ) Less: Net income (loss) attributable to noncontrolling interests 46 Net income (loss) attributable to the Partnership $ (1,238 ) Segment gross margin (a) $ 41,265 $ 19,394 $ 5,422 $ 66,081 (a) Segment gross margin for our Gathering and Processing segment consists of total revenue less (i) unrealized gains on commodity derivatives of $0.1 million , (ii) COMA income of $0.4 million and (iii) purchases of natural gas, NGLs and condensate. Segment gross margin for our Transmission segment consists of total revenue less COMA income of $0.1 million and purchases of natural gas, NGLs and condensate. Segment gross margin for our Terminals segment consists of total revenue less direct operating expenses. A reconciliation of total assets by segment to the amounts included in the condensed consolidated balance sheets follows: June 30, December 31, 2016 2015 Segment assets: Gathering and Processing $ 586,782 $ 572,824 Transmission 151,518 133,870 Terminals 94,790 84,449 Other (a) 317,878 100,153 Total assets $ 1,150,968 $ 891,296 (a) Other assets not allocable to segments consist of investment in unconsolidated affiliates, corporate leasehold improvements and other assets.

Organization and Basis of Pre40

Organization and Basis of Presentation (Details) mi in Thousands, bbl in Millions	6 Months Ended
	Jun. 30, 2016facilitypipelinegathering_systemmibbl
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General Partners' Capital Account, Percentage	95.00%
Limited Partners' Capital Account, Percentage	5.00%
Number of Gathering Systems | gathering_system	13
Number of Processing Facilities | facility	5
Number of Fractionation Facilities | facility	3
Number of Marine Terminal Sites | facility	3
Number of Interstate Pipelines | pipeline	3
Number of Intrastate Pipelines | pipeline	5
Number of Oil Pipelines | pipeline	1
Length Of Pipeline | mi	3
Million barrels of storage capacity | bbl	2.2

Acquisitions and Divestitures E

Acquisitions and Divestitures Eloi Bay Divestiture (Details) - USD ($) $ in Thousands	Jun. 01, 2015	Jun. 30, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net		$ 683,109	$ 648,013
Eloi Bay [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Net	$ 3,000
Gain (Loss) on Disposition of Property Plant Equipment	$ 3,000

Acquisitions and Divestitures D

Acquisitions and Divestitures Delta House Acquisition (Details) - USD ($) $ in Thousands	Apr. 25, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Sep. 18, 2015
Schedule of Equity Method Investments [Line Items]
Class A Units of Delta House Oil and Gas Lateral LLC	53.5
Initial investment				$ 221,899
Earnings in unconsolidated affiliates		$ 11,647	$ 4	18,990	$ 171
Distributions from unconsolidated affiliates				18,990	171
Class A Units of Delta House FPS LLC	912.4
Payments to Acquire Equity Method Investments				11,444	$ 626
D-Day Offshore Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	100.00%
Pinto Offshore Holdings LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage						26.30%
Delta House FPS LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage						49.00%
Delta House [Member]
Schedule of Equity Method Investments [Line Items]
Initial investment	$ 9,900			9,873
Earnings in unconsolidated affiliates				14,264
Distributions from unconsolidated affiliates				$ 1,100
Equity Method Investment, Ownership Percentage		13.90%		13.90%
Delta House, D-Day [Member]
Schedule of Equity Method Investments [Line Items]
Earnings in unconsolidated affiliates				$ 400

Acquisitions and Divestitures43

Acquisitions and Divestitures Emerald Transaction (Details)	Apr. 27, 2016USD ($)billion_cubic_feet / dlateralplatformmi	Apr. 25, 2016USD ($)billion_cubic_feet_per_daymi	Apr. 15, 2016mi	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)billion_cubic_feet / dmi	Jun. 30, 2015USD ($)
Schedule of Equity Method Investments [Line Items]
Initial investment						$ 221,899,000
Payments to Acquire Equity Method Investments						$ 11,444,000	$ 626,000
Length Of Pipeline | mi						3,000
Volume of Natural Gas, Operating Amount | billion_cubic_feet / d						1
Preferred Units, Contributed Capital		$ 8,571,429
Earnings in unconsolidated affiliates				$ 11,647,000	$ 4,000	$ 18,990,000	171,000
Distributions from unconsolidated affiliates						18,990,000	171,000
Number of Platforms | platform	2
Number of laterals | lateral	1
Total Consideration for Issuance of Preferred Units		120,000,000		$ 120,000,000	$ 0	$ 120,000,000	$ 0
Borrowings to acquire equity method investments	$ 91,000,000
Okeanos [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage				66.70%		66.70%
Length Of Pipeline | mi	100
Volume of Natural Gas, Operating Amount | billion_cubic_feet / d	1
Emerald Transaction [Member]
Schedule of Equity Method Investments [Line Items]
Initial investment						$ 212,000,000
Payments to Acquire Equity Method Investments	$ 27,400,000	$ 183,600,000
Earnings in unconsolidated affiliates						4,200,000
Distributions from unconsolidated affiliates						5,400,000
Destin [Member]
Schedule of Equity Method Investments [Line Items]
Initial investment						$ 122,830,000
Equity Method Investment, Ownership Percentage				49.70%		49.70%
Length Of Pipeline | mi		260
Volume of Natural Gas, Operating Amount | billion_cubic_feet_per_day		1.2
Earnings in unconsolidated affiliates						$ 2,027,000
Length Of Offshore Pipeline | mi		120
Length Of Onshore Pipeline | mi		135
Tri-State [Member]
Schedule of Equity Method Investments [Line Items]
Initial investment						$ 56,681,000
Equity Method Investment, Ownership Percentage				16.70%		16.70%
Length Of Pipeline | mi		160
Earnings in unconsolidated affiliates						$ 869,000
Wilprise [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage				25.30%		25.30%
Length Of Pipeline | mi		30
American Panther [Member]
Schedule of Equity Method Investments [Line Items]
Length Of Pipeline | mi			200
General Partner [Member]
Schedule of Equity Method Investments [Line Items]
Partners Capital Account Contributions, Emerald						$ 1,000,000

Acquisitions and Divestitures A

Acquisitions and Divestitures American Panther Acquisition (Details) - USD ($) $ in Thousands	Apr. 15, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Business Acquisition [Line Items]
Revenues		$ 55,382	$ 67,509	$ 101,402	$ 132,118
Operating Income (Loss)		$ (6,191)	$ 1,867	$ (11,306)	$ 5,302
American Panther [Member]
Business Acquisition [Line Items]
Percentage of voting interests acquired		60.00%		60.00%
Revenues				$ 4,300
Operating Income (Loss)				2,600
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Pipelines	$ 16,952
Payments to Acquire Businesses, Gross	3,073
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Land	421
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	17,373
Business Combination Recognized Identifiable Assets Acquired and Liabilities Assumed, ARO	$ (14,300)
Business Acquisition, Transaction Costs		$ 200		$ 200

Concentration of Credit Risk 45

Concentration of Credit Risk and Trade Accounts Receivable (Details)	3 Months Ended	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2016
Risks and Uncertainties [Abstract]
Concentration Risk, Percentage	10.00%	11.00%

Other Current Assets (Details)

Other Current Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Prepaid insurance	$ 3,073	$ 3,948
Accrued distributions from unconsolidated affiliates	4,359	0
Other prepaid amounts	2,108	2,866
Other current assets	3,808	3,280
Other Assets, Current	$ 13,348	$ 10,094

Derivatives (Fair Value of Comm

Derivatives (Fair Value of Commodity Derivatives) (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Derivative [Line Items]
Gross Risk Management Assets	$ 944	$ 365
Gross Risk Management Liabilities	0	0
Net Risk Management Assets (Liabilities)	944	365
Gross Risk Management Assets	0	0
Gross Risk Management Liabilities	(3,388)	0
Net Risk Management Assets (Liabilities)	(3,388)	0
Risk Management Assets [Member] | Commodity derivatives [Member]
Derivative [Line Items]
Gross Risk Management Assets	944	365
Gross Risk Management Liabilities	0	0
Net Risk Management Assets (Liabilities)	944	365
Risk Management Assets - Long Term [Member] | Commodity derivatives [Member]
Derivative [Line Items]
Gross Risk Management Assets	0	0
Gross Risk Management Liabilities	0	0
Net Risk Management Assets (Liabilities)	0	0
Risk Management Liabilities [Member] | Commodity derivatives [Member]
Derivative [Line Items]
Gross Risk Management Assets	0	0
Gross Risk Management Liabilities	(832)	0
Net Risk Management Assets (Liabilities)	(832)	0
Risk Management Liabilities - Long Term [Member] | Commodity derivatives [Member]
Derivative [Line Items]
Gross Risk Management Assets	0	0
Gross Risk Management Liabilities	(2,556)	0
Net Risk Management Assets (Liabilities)	$ (2,556)	$ 0

Derivatives (Realized and Unrea

Derivatives (Realized and Unrealized Gains (Losses)) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Derivatives, Fair Value [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ (766)	$ 311	$ (869)	$ 458
Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(476)	(83)	(694)	(287)
Gain on commodity derivatives, net	(2,555)	157	(3,388)	213
Gain (Loss) on Derivative Instruments [Member] | Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(244)	252	(244)	391
Gain on commodity derivatives, net	(522)	59	(625)	67
Interest Expense [Member] | Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0	(101)	0	(203)
Gain on commodity derivatives, net	(2,033)	98	(2,763)	146
Other Income [Member] | Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(232)	(234)	(450)	(475)
Gain on commodity derivatives, net	$ 0	$ 0	$ 0	$ 0

Derivatives (Details Textual)

Derivatives (Details Textual) $ in Thousands, gal in Millions	6 Months Ended
	Jun. 30, 2016USD ($)gal	Jun. 30, 2015USD ($)
Derivative [Line Items]
Aggregate notional volume of our commodity derivative | gal	5.6
Amortization of weather derivative premium	$ 451	$ 475
Interest Rate Swap [Member]
Derivative [Line Items]
Notional amount of interest rate swap	300,000
Weather Contract [Member]
Derivative [Line Items]
Potential proceeds from derivative contract	30,000
Payment for weather derivative premium	$ (1,000)	$ (900)
Derivative term of contract	1 year
Amortization of weather derivative premium	$ 900
Wells Fargo Swap 1 [Member] | Interest Rate Swap [Member]
Derivative [Line Items]
Notional amount of interest rate swap	200,000
Wells Fargo Swap 2 [Member] | Interest Rate Swap [Member]
Derivative [Line Items]
Notional amount of interest rate swap	$ 100,000

Fair Value Measurement (Details

Fair Value Measurement (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, net:	$ (625)	$ 0
Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, net:	(2,763)	0
Estimate of Fair Value Measurement [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, net:	(625)	0
Estimate of Fair Value Measurement [Member] | Commodity Contract [Member] | Level 1 [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, net:	0	0
Estimate of Fair Value Measurement [Member] | Commodity Contract [Member] | Level 2 [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, net:	(625)	0
Estimate of Fair Value Measurement [Member] | Commodity Contract [Member] | Level 3 [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, net:	0	0
Estimate of Fair Value Measurement [Member] | Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, net:	(2,763)	0
Estimate of Fair Value Measurement [Member] | Interest Rate Swap [Member] | Level 1 [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, net:	0	0
Estimate of Fair Value Measurement [Member] | Interest Rate Swap [Member] | Level 2 [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, net:	(2,763)	0
Estimate of Fair Value Measurement [Member] | Interest Rate Swap [Member] | Level 3 [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, net:	$ 0	$ 0

Property, Plant and Equipment51

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Interest Costs Capitalized	$ 500	$ 500	$ 1,000	$ 700
Property, Plant and Equipment, Net [Abstract]
Accumulated depreciation	(164,134)		(164,134)		$ (145,963)
Property, plant and equipment, net	683,109		683,109		648,013
Land [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	5,703		5,703		5,282
Construction in progress [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	61,203		61,203		46,045
Buildings and improvements [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	9,959		9,959		9,864
Processing and treating plants [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	102,003		102,003		97,784
Pipelines [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	573,084		573,084		554,400
Tanks, truck rack and piping [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	58,226		58,226		58,394
Equipment [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	37,065		37,065		22,207
Property, Plant And Equipment [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	$ 847,243		$ 847,243		$ 793,976
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] | Tanks, truck rack and piping [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life			40 years
Maximum [Member] | Equipment [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life			20 years
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			3 years
Minimum [Member] | Tanks, truck rack and piping [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life			20 years
Minimum [Member] | Equipment [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life			5 years

Property, Plant and Equipment52

Property, Plant and Equipment (Details Textual) - USD ($) $ in Millions	Feb. 12, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Interest Costs Capitalized		$ 0.5	$ 0.5	$ 1	$ 0.7
Depreciation		9.4	$ 7.6	18.2	$ 15.5
EscrowedUnitsReturnedtoPartnership	1,034,483
Payments for Previous Acquisition	$ 0.7
AlaTenn system [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment gross		$ 132		$ 132		$ 111.9

Goodwill and Intangible Asset53

Goodwill and Intangible Assets, Net (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Segment Reporting Information [Line Items]
Goodwill	$ 16,262		$ 16,262		$ 16,262
Amortization of Intangible Assets	$ 1,100	$ 1,500	$ 2,200	$ 3,100
Minimum [Member]
Segment Reporting Information [Line Items]
Finite-Lived Intangible Asset, Useful Life			10 years
Maximum [Member]
Segment Reporting Information [Line Items]
Finite-Lived Intangible Asset, Useful Life			30 years

Goodwill and Intangible Asset54

Goodwill and Intangible Assets, Net Schedule of Intangible Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount:	$ 106,750	$ 106,750
Accumulated amortization:	(7,960)	(5,785)
Net carrying amount:	98,790	100,965
Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount:	53,400	53,400
Accumulated amortization:	(4,410)	(3,124)
Net carrying amount:	48,990	50,276
Dedicated Acreage [Member]
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount:	53,350	53,350
Accumulated amortization:	(3,550)	(2,661)
Net carrying amount:	$ 49,800	$ 50,689

Investment in unconsolidated 55

Investment in unconsolidated affiliates Partnership's Equity Investments (Details) - USD ($) $ in Thousands	Apr. 25, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 82,301
Initial investment				221,899
Earnings in unconsolidated affiliates		$ 11,647	$ 4	18,990	$ 171
Contributions				12,459
Distributions				(40,077)
Balances		$ 295,572		$ 295,572
Destin [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		49.70%		49.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 0
Initial investment				122,830
Earnings in unconsolidated affiliates				2,027
Contributions				0
Distributions				(6,631)
Balances		$ 118,226		$ 118,226
Tri-State [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		16.70%		16.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 0
Initial investment				56,681
Earnings in unconsolidated affiliates				869
Contributions				0
Distributions				(1,092)
Balances		$ 56,458		$ 56,458
Delta House [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		13.90%		13.90%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 56,525
Initial investment	$ 9,900			9,873
Earnings in unconsolidated affiliates				14,264
Contributions				0
Distributions				(28,359)
Balances		$ 52,303		$ 52,303
Wilprise [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		25.30%		25.30%
Okeanos [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		66.70%		66.70%
MPOG [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		66.70%		66.70%
Mesquite [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		47.30%		47.30%
Other Equity Method Investments [Member]
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 25,776
Initial investment				32,515
Earnings in unconsolidated affiliates				1,830
Contributions				12,459
Distributions				(3,995)
Balances		$ 68,585		$ 68,585

Investment in unconsolidated 56

Investment in unconsolidated affiliates Financial Information for the Partnership's Equity Investments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Equity Method Investments and Joint Ventures [Abstract]
Current assets	$ 170,283		$ 170,283		$ 2,086
Non-current assets	1,470,286		1,470,286		288,617
Current liabilities	182,895		182,895		366
Non-current liabilities	475,602		475,602		$ 23,617
Total revenue	87,054	$ 1,974	151,997	$ 4,410
Operating expense	6,649	768	7,541	1,738
Net income	$ 65,613	$ (2)	$ 120,777	$ 241

Accrued Expenses and Other Cu57

Accrued Expenses and Other Current Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Other Liabilities Disclosure [Abstract]
Current portion of ARO	$ 6,826	$ 6,822
Accrued capital expenditures	8,299	3,984
Accrued expenses	11,788	3,178
Due to related parties	2,424	3,894
Other	7,740	7,157
Accrued expenses and other current liabilities	$ 37,077	$ 25,035

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2016	Dec. 31, 2015
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning asset retirement obligation	$ 35,371
Liabilities assumed	14,300
Expenditures	(11)
Accretion expense	596
Total ending asset retirement obligation	$ 35,371	$ 50,256	$ 35,371
Less: current portion		6,826	6,822
Long-term asset retirement obligation		$ 43,430	28,549
Restricted Cash and Cash Equivalents			$ 5,000

Debt Obligations (Details)

Debt Obligations (Details) $ in Thousands	Jun. 30, 2016USD ($)	Dec. 31, 2015USD ($)
Debt Disclosure [Abstract]
Ratio of Indebtedness to Net Capital	4.15
Revolving credit facility	$ 672,400	$ 525,100
Other debt	731	2,338
Total debt	673,131	527,438
Less: current portion	731	2,338
Long-term debt	$ 672,400	$ 525,100
Debt Instrument, Interest Coverage Ratio	8.86

Debt Obligations (Details Textu

Debt Obligations (Details Textual) $ in Thousands	6 Months Ended
	Jun. 30, 2016USD ($)	Dec. 31, 2015USD ($)	Jun. 30, 2015
Long-Term Debt (Textual) [Abstract]
Line of Credit Facility, Current Borrowing Capacity	$ 750,000
Line of Credit Facility, Amount Outstanding Limit	900,000
Letters of Credit Outstanding, Amount	5,400
Revolving credit facility	$ 672,400	$ 525,100
Ratio of Indebtedness to Net Capital	4.15
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	0.50%
Debt Instrument, Interest Coverage Ratio	8.86
Debt, Weighted Average Interest Rate	4.35%		3.15%
Proceeds from (Payments for) Other Financing Activities	$ 3,000
Debt Instrument, Periodic Payment	$ 300
Maximum [Member]
Long-Term Debt (Textual) [Abstract]
Ratio of Indebtedness to Net Capital	4.75
Ratio of indebtedness to net capital, after permitted acquisition	5.25
Minimum [Member]
Long-Term Debt (Textual) [Abstract]
Debt Instrument, Interest Coverage Ratio	2.50
Base Rate [Member] | Maximum [Member]
Long-Term Debt (Textual) [Abstract]
Debt Instrument, Basis Spread on Variable Rate	3.25%
Base Rate [Member] | Minimum [Member]
Long-Term Debt (Textual) [Abstract]
Debt Instrument, Basis Spread on Variable Rate	2.00%
Federal Funds [Member]
Long-Term Debt (Textual) [Abstract]
Debt Instrument, Interest Rate, Stated Percentage	0.50%
Eurodollar [Member]
Long-Term Debt (Textual) [Abstract]
Debt Instrument, Interest Rate, Stated Percentage	1.00%
Eurodollar [Member] | Maximum [Member]
Long-Term Debt (Textual) [Abstract]
Debt Instrument, Basis Spread on Variable Rate	2.25%
Eurodollar [Member] | Minimum [Member]
Long-Term Debt (Textual) [Abstract]
Debt Instrument, Basis Spread on Variable Rate	1.00%
Insurance Premium Financing [Member]
Long-Term Debt (Textual) [Abstract]
Debt Instrument, Interest Rate, Stated Percentage	3.95%

Partners' Capital (Details)

Partners' Capital (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Aug. 05, 2016	Apr. 25, 2016	Dec. 31, 2015
Fair Value of Warrant Unit						$ 4.41
Fair Value Assumptions, Expected Volatility Rate			42.00%
Stock and Warrants Issued During Period, Value, Preferred Stock and Warrants			$ 4,481,000
General Partners' Capital Account, Period Distribution Amount			$ 1,800,000	$ 300,000
Partners' Capital Account, Units, Sold in Public Offering			248,561
Unitholder distributions	$ (12,918,000)	$ (12,205,000)	$ (29,964,000)	(24,364,000)
Proceeds from Issuance Initial Public Offering			3,200,000
Limited Partners' Offering Costs	100,000		100,000
AggregateOfferingPrice	$ 96,800,000		$ 96,800,000
General Partners' Capital Account, Units Issued	664,000		664,000				536,000
Preferred Units, Contributed Capital						$ 8,571,429
Class of Warrant or Right, Number of Securities Called by Warrants or Rights						800,000
Class of Warrant or Right, Exercise Price of Warrants or Rights						$ 7.25
Number of units in warrant calculation						400,000
Stipulated Deduction in Warrant Calculation						$ 45,000,000
Partnership Interest [Member]
General partner interest units	664,000		664,000				536,000
Series C [Member]
Distribution Made to Limited Partner, Cash Distributions Paid			$ 1,300,000
Accrued and paid-in-kind unitholder distribution for Units			900,000
Series A [Member]
Distribution Made to Limited Partner, Cash Distributions Paid			2,400,000
Accrued and paid-in-kind unitholder distribution for Units			2,200,000
Series B [Member]
Unitholder distributions	$ 0	(413,000)	$ 0	(833,000)
Series A Preferred Stock [Member]
Fair Value Inputs, Discount Rate			10.00%
Accrued and paid-in-kind unitholder distribution for Units			$ 9,100,000	7,600,000
Convertible preferred, units, outstanding	9,797,000		9,797,000		9,797,342		9,210,000
Limited Partner Series B Convertible Units [Member]
Units Issued	0		0				1,350,000
Limited Partner Series B Convertible Units [Member] | Series B [Member]
Preferred, units, outstanding	0		0				1,350,000
Series C Preferred Stock [Member]
Fair Value Inputs, Discount Rate			18.00%
Accrued and paid-in-kind unitholder distribution for Units			$ 2,249,000	0
Convertible preferred, units, outstanding	8,571,000		8,571,000				0
Limited Partner Common Units [Member]
Units Issued	31,146,000		31,146,000				30,427,000
Limited Partner Common Units [Member] | Partnership Interest [Member]
Preferred, units, outstanding	31,146,000		31,146,000				30,427,000
Limited Partner [Member]
Unitholder distributions	$ (12,745,000)	(10,753,000)	$ (27,763,000)	(21,466,000)
General Partner [Member]
Unitholder distributions	(173,000)	(159,000)	(395,000)	(317,000)
General Partner, Incentive Distribution Rights [Member]
Unitholder distributions	$ 0	$ (1,293,000)	$ (1,806,000)	(2,581,000)
Series C [Member]
Investment Options, Exercise Price			$ 14
General Partner [Member]
Unitholder distributions			$ (2,351,000)	$ (3,004,000)
General Partners' Capital Account, Units Issued	128,272	18,706	128,272	18,706

Partners Capital (Details Textu

Partners Capital (Details Textual) $ / shares in Units, $ in Thousands		Jul. 21, 2016$ / shares	Jun. 30, 2016USD ($)$ / sharesshares	Mar. 31, 2016$ / unit	Jun. 30, 2015USD ($)$ / sharesshares	Mar. 31, 2015$ / unit	Jun. 30, 2016USD ($)$ / sharesshares	Jun. 30, 2015USD ($)$ / sharesshares	Dec. 31, 2015shares
Subsidiary, Sale of Stock [Line Items]
Distribution declared per common unit (a) | $ / shares	[1]		$ 0.4125		$ 0.4725		$ 0.8850	$ 0.9450
Unitholder distributions			$ (12,918)		$ (12,205)		$ (29,964)	$ (24,364)
Partners Capital (Textual) [Abstract]
General partner interest							1.30%
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest							98.70%
General Partners' Capital Account, Period Distribution Amount							$ 1,800	300
General Partners' Capital Account, Units Issued | shares			664,000				664,000		536,000
Fair value input, option value | $ / unit				0.02		1.88
Limited Partner [Member]
Subsidiary, Sale of Stock [Line Items]
Unitholder distributions							$ (38,935)	(29,800)
General Partner [Member]
Subsidiary, Sale of Stock [Line Items]
Unitholder distributions							$ (2,351)	$ (3,004)
Partners Capital (Textual) [Abstract]
General Partners' Capital Account, Units Issued | shares			128,272		18,706		128,272	18,706
Series A [Member]
Partners Capital (Textual) [Abstract]
Distribution Made to Limited Partner, Cash Distributions Paid							$ 2,400
Accrued and paid-in-kind unitholder distribution for Units							2,200
Series B [Member]
Subsidiary, Sale of Stock [Line Items]
Unitholder distributions			$ 0		$ (413)		$ 0	$ (833)
Subsequent Event [Member]
Subsidiary, Sale of Stock [Line Items]
Distribution declared per common unit (a) | $ / shares		$ 0.4125
Distribution Made to Limited Partner, Distributions Declared, Per Unit, Annualized Basis | $ / shares		$ 1.65
Dividend Paid [Member] | Series A [Member]
Partners Capital (Textual) [Abstract]
Units Issued | shares			586,882		365,641		586,882	365,641
Series A Preferred Stock [Member]
Partners Capital (Textual) [Abstract]
Accrued and paid-in-kind unitholder distribution for Units							$ 9,100	$ 7,600
Fair Value Inputs, Discount Rate							10.00%
[1]	Distributions declared and paid each quarter related to prior periods' quarter.

Partners' Capital (Calculation

Partners' Capital (Calculation of Net Income (Loss) Per Limited Partner Unit) (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income (loss) from continuing operations	$ (3,591)	$ (2,002)	$ (7,555)	$ (1,166)
Less: Comprehensive income (loss) attributable to noncontrolling interests	(992)	(32)	(979)	(46)
Income (Loss) from Continuing Operations Attributable to Parent	(4,583)	(2,034)	(8,534)	(1,212)
Temporary Equity, Dividends, Adjustment	4,602	4,196	9,073	7,607
Unitholder distributions	(12,918)	(12,205)	(29,964)	(24,364)
General Partners' Capital Account, Period Undistributed Income (Loss) From Continuing Operations, Amount	(322)	(234)	(659)	(422)
Net income (loss) from continuing operations available to Limited Partners	(11,285)	(7,861)	(21,398)	(12,129)
Net income (loss) from discontinued operations available to Limited Partners	0	(31)	0	(26)
Net income (loss) available to Limited Partners	$ (11,285)	$ (7,892)	$ (21,398)	$ (12,155)
Weighted Average Number of Shares Outstanding, Basic	30,949	22,757	30,884	22,730
Net Income (Loss), Per Outstanding Limited Partnership Unit, Basic, Net of Tax	$ (0.36)	$ (0.35)	$ (0.69)	$ (0.53)
Series C Preferred Stock [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Temporary Equity, Dividends, Adjustment	$ 2,249	$ 0	$ 2,249	$ 0
Series B [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Unitholder distributions	0	(413)	0	(833)
General Partner [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Unitholder distributions			(2,351)	(3,004)
Dividend Declared [Member] | General Partner [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Unitholder distributions	$ (173)	$ (1,452)	$ (2,201)	$ (2,899)

Long-Term Incentive Plan (Detai

Long-Term Incentive Plan (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Dec. 31, 2015	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Feb. 11, 2016	Nov. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized						6,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant	15,484	4,941,325		4,941,325
Grants Issued Under Long Term Incentive Plan		25.00%		25.00%
Equity compensation expense		$ 1,025	$ 550	$ 2,109	$ 2,248
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value				1,000	2,300
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized		5,000	$ 6,000	$ 5,000	$ 6,000
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition				2 years 5 months 5 days
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Nonvested							$ 2,000
Employee Service Share-based Compensation, Nonvested Awards, Compensation Not yet Recognized, Stock Options		$ 100		$ 100
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Outstanding at beginning of period				569,759
Granted				1,177,509
Forfeited				(102,934)
Vested				(179,326)
Outstanding at end of period	569,759	1,465,008		1,465,008
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Weighted Average [Roll Forward]
Outstanding at beginning of period				$ 13.15
Granted				1.05
Forfeited				5.36
Vested				11.75
Outstanding at end of period	$ 13.15	$ 4.14		$ 4.14
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Outstanding at beginning of period				200,000
Granted	200,000			0
Forfeited				0
Vested				0
Outstanding at end of period	200,000	200,000		200,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Weight Average [Roll Forward]
Outstanding at beginning of period				$ 7.50
Granted				0
Forfeited				0
Vested				0
Outstanding at end of period	$ 7.50	$ 7.50		$ 7.50
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity compensation expense		$ 400		$ 600
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized		$ 900		$ 900

Income Tax (Details)

Income Tax (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Income Tax Disclosure [Abstract]
Income tax (expense) benefit	$ (540)	$ (317)	$ (860)	$ (473)
Effective Income Tax Rate, Continuing Operations	(17.70%)	(18.80%)	(12.80%)	(68.30%)

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016USD ($)
Commitments and Contingencies [Abstract]
Business Exit Costs	$ 3.6
AccruedBusinessExitCosts	2.5
Commitments, Fair Value Disclosure	$ 15.9

Related- Party Transactions (De

Related- Party Transactions (Details Textual) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Related Party Transactions (Textual) [Abstract]
Business Development	$ (0.1)	$ (0.5)	$ (0.4)	$ (0.9)
Management Fees Revenue	0.2	0.4	0.4	0.9
Related Party Transaction, Due from (to) Related Party					$ 3.8
American Midstream, L.L.C [Member]
Related Party Transactions (Textual) [Abstract]
General and Administrative Expense	8.9	6.9	16.9	14.2
Business Development	(0.3)	$ (0.5)	(0.2)	$ (0.9)
General Partner [Member]
Related Party Transactions (Textual) [Abstract]
Related Party Transaction, Due from (to) Related Party	$ 2.4		$ 2.4

Reporting Segments (Details)

Reporting Segments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Segment Reporting, Revenue Reconciling Item [Line Items]
Segment assets:	$ 1,150,968		$ 1,150,968		$ 891,296
Segment information
Revenue	56,148	$ 67,198	102,271	$ 131,660
Gain (loss) on commodity derivatives, net	(766)	311	(869)	458
Total revenue	55,382	67,509	101,402	132,118
Purchases of natural gas, NGLs and condensate	22,102	33,334	39,014	62,311
Direct operating expenses	16,191	13,967	30,712	27,834
Selling, general and administrative expenses	11,432	5,571	19,966	12,506
Equity compensation expense	1,025	550	2,109	2,248
Depreciation, amortization and accretion expense	10,903	9,250	20,997	18,939
Total operating expenses	61,653	62,672	112,798	123,838
Gain (loss) on sale of assets, net	80	(2,970)	90	(2,978)
Interest expense	(8,507)	(3,556)	(14,379)	(6,166)
Earnings in unconsolidated affiliates	11,647	4	18,990	171
Income tax (expense) benefit	(540)	(317)	(860)	(473)
Income (loss) from discontinued operations, net of tax	0	(31)	0	(26)
Net income (loss)	(3,591)	(2,033)	(7,555)	(1,192)
Less: Net income (loss) attributable to noncontrolling interests	(992)	(32)	(979)	(46)
Net income (loss) attributable to the Partnership	(4,583)	(2,065)	(8,534)	(1,238)
Segment gross margin	32,291	32,304	59,848	66,081
Gathering and Processing reporting segment [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
COMA Income	(100)	200	(100)	400
Segment information
Revenue	41,780	50,439	72,928	98,888
Gain (loss) on commodity derivatives, net	(764)	311	(867)	458
Total revenue	41,016	50,750	72,061	99,346
Purchases of natural gas, NGLs and condensate	20,964	30,272	36,412	57,590
Direct operating expenses	11,231	9,130	21,234	18,223
Segment gross margin	20,605	20,219	36,336	41,265
Transmission reporting segment [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
COMA Income	100
Segment information
Revenue	8,740	12,423	18,967	24,171
Gain (loss) on commodity derivatives, net	(2)	0	(2)	0
Total revenue	8,738	12,423	18,965	24,171
Purchases of natural gas, NGLs and condensate	1,138	3,062	2,602	4,721
Direct operating expenses	3,425	3,253	6,266	6,432
Segment gross margin	7,593	9,333	16,348	19,394
Terminals reporting segment [Member]
Segment information
Revenue	5,628	4,336	10,376	8,601
Gain (loss) on commodity derivatives, net	0	0	0	0
Total revenue	5,628			8,601
Purchases of natural gas, NGLs and condensate	0	0	0	0
Direct operating expenses	1,535	1,584	3,212	3,179
Segment gross margin	4,093	2,752	7,164	5,422
Gathering And Processing [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Segment assets:	586,782		586,782		572,824
Transmission [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
COMA Income		100	100	100
Segment assets:	151,518		151,518		133,870
Terminals [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Segment assets:	94,790		94,790		84,449
Segment information
Total revenue		4,336	10,376
Other Segments [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Segment assets:	317,878		317,878		$ 100,153
Commodity Contract [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Unrealized Gain (Loss) on Derivatives	(2,555)	157	(3,388)	213
Segment information
Gain (loss) on commodity derivatives, net	(476)	(83)	(694)	(287)
Gain (Loss) on Derivative Instruments [Member] | Commodity Contract [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Unrealized Gain (Loss) on Derivatives	(522)	59	(625)	67
Segment information
Gain (loss) on commodity derivatives, net	$ (244)	$ 252	$ (244)	$ 391

Reporting Segments (Details Tex

Reporting Segments (Details Textual)	6 Months Ended
	Jun. 30, 2016segment
Segment Reporting [Abstract]
Number of Operating Segments	3