Third Coast Midstream (AMID) 10-Q 9 Nov 17 2017 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2017	Oct. 27, 2017
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	Sep. 30, 2017
Amendment Flag	false
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding (in shares)		52,684,359
Series A [Member]
Document Information [Line Items]
Entity Common Stock, Shares Outstanding (in shares)		10,536,915
Series C [Member]
Document Information [Line Items]
Entity Common Stock, Shares Outstanding (in shares)		8,792,205

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Current assets
Cash and cash equivalents	$ 6,739	$ 5,666
Restricted cash	18,683	0
Accounts receivable, net of allowance for doubtful accounts of $0.1 and $0.6 million, respectively	25,897	14,715
Unbilled revenue	53,168	52,910
Inventory	5,970	1,990
Other current assets	17,144	25,516
Current assets of discontinued operations	0	22,727
Total current assets	127,601	123,524
Risk management assets-long term	7,545	10,627
Property, plant and equipment, net	1,140,826	1,066,608
Goodwill	202,135	202,135
Restricted cash-long term	5,693	323,564
Intangible assets, net	194,456	205,071
Investments in unconsolidated affiliates	334,026	291,987
Other assets, net	10,925	11,773
Total noncurrent assets of discontinued operations	0	114,032
Total assets	2,023,207	2,349,321
Current liabilities
Accounts payable	27,285	39,569
Accrued gas purchases	16,696	7,891
Accrued expenses and other current liabilities	67,505	72,721
Current portion of long-term debt	1,234	5,438
Current liabilities of discontinued operations	0	14,319
Total current liabilities	112,720	139,938
Asset retirement obligations	52,046	44,363
Other long-term liabilities	2,448	1,858
3.77% Senior secured notes (Non-recourse)	55,186	55,979
8.50% Senior unsecured notes	293,007	291,309
Revolving credit facility	709,652	888,250
Deferred tax liability	9,695	8,205
Noncurrent liabilities of discontinued operations	0	172
Total liabilities	1,234,754	1,430,074
Commitments and contingencies
Convertible preferred units	343,579	334,090
Equity and partners’ capital
General Partner interests (953 thousand and 680 thousand units issued and outstanding as of September 30, 2017 and December 31, 2016, respectively)	(86,224)	(47,645)
Limited Partner interests (52,740 thousand and 51,351 thousand units issued and outstanding as of September 30, 2017 and December 31, 2016, respectively)	517,081	616,087
Accumulated other comprehensive income (loss)	2	(40)
Total partners’ capital	430,859	568,402
Noncontrolling interests	14,015	16,755
Total equity and partners’ capital	444,874	585,157
Total liabilities, equity and partners’ capital	$ 2,023,207	$ 2,349,321

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Sep. 30, 2017	Mar. 08, 2017	Dec. 31, 2016	Dec. 28, 2016	Sep. 30, 2016
Allowance for doubtful accounts receivable	$ 0.1		$ 0.6
General partner interest units, outstanding (in shares)	953		680
Preferred, units, outstanding (in shares)	52,740		51,351
Partnership Interest [Member]
General partner interest, units issued (in shares)	953		680
General partner interest units, outstanding (in shares)	953		680
Preferred, units, issued (in shares)	52,740		51,351
Preferred, units, outstanding (in shares)	52,740		51,351
3.77% Senior Notes [Member] | Senior Notes [Member]
Debt instrument, interest rate, stated percentage	3.77%		3.77%		3.77%
8.50% Senior Notes [Member] | Senior Notes [Member]
Debt instrument, interest rate, stated percentage	8.50%	8.50%	8.50%	8.50%

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Revenue:
Commodity sales		$ 124,052	$ 119,194	$ 372,049	$ 304,084
Services		38,835	40,385	116,382	110,998
Gain (loss) on commodity derivatives, net		(597)	324	(33)	(1,929)
Total revenue		162,290	159,903	488,398	413,153
Operating expenses:
Costs of sales		112,398	107,249	342,886	270,712
Direct operating expenses		20,705	17,571	56,819	53,872
Corporate expenses		27,083	22,103	84,570	60,945
Depreciation, amortization and accretion		26,781	22,668	78,834	65,937
(Gain) loss on sale of assets, net		(4,061)	36	(4,064)	297
Total operating expenses		182,906	169,627	559,045	451,763
Operating loss		(20,616)	(9,724)	(70,647)	(38,610)
Other income (expense), net
Interest expense		(17,759)	(5,830)	(51,037)	(24,723)
Other income (expense), net		34,085	(1)	32,248	245
Earnings in unconsolidated affiliates		16,827	10,468	49,781	29,513
Income (loss) from continuing operations before income taxes		12,537	(5,087)	(39,655)	(33,575)
Income tax expense		(731)	(401)	(2,611)	(1,839)
Income (loss) from continuing operations		11,806	(5,488)	(42,266)	(35,414)
Income (loss) from discontinued operations, including net gain on disposition of $46.5 million (Note 4)		44,696	(2,310)	42,185	7,532
Net income (loss)		56,502	(7,798)	(81)	(27,882)
Less: Net income attributable to noncontrolling interests		621	1,241	3,386	2,192
Net income (loss) attributable to the Partnership		55,881	(9,039)	(3,467)	(30,074)
General Partner’s interest in net income (loss)		697	(31)		(235)
Limited Partners’ interest in net income (loss)		$ 55,184	$ (9,008)	$ (3,369)	$ (29,839)
Distribution declared per common unit (in usd per share)	[1]	$ 0.4125	$ 0.4125	$ 1.2375	$ 1.2975
Limited Partners’ net income (loss) per common unit, basic and diluted:
Income (loss) from continuing operations (in usd per share)		0.05	(0.29)	(1.35)	(1.14)
Income (loss) from discontinued operations (in usd per share)		0.86	(0.05)	0.81	0.15
Net income (loss) (in usd per share)		$ 0.91	$ (0.34)	$ (0.54)	$ (0.99)
Weighted average number of common units outstanding:
Weighted average number of common units outstanding: basic and diluted (shares)		52,021	51,310	52,021	51,310
[1]	Declared and paid each quarter related to prior quarter.

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Operations (Unaudited) Condensed Consolidated Statements of Operations (Unaudited) (Parenthetical) $ in Millions	9 Months Ended
	Sep. 30, 2017USD ($)
Income Statement [Abstract]
Gain from the sale of discontinued operations	$ 46.5

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Comprehensive Income (Loss) (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 56,502	$ (7,798)	$ (81)	$ (27,882)
Unrealized gain (loss) related to postretirement benefit plan	0	(2)	42	33
Comprehensive income (loss)	56,502	(7,800)	(39)	(27,849)
Less: Comprehensive income attributable to noncontrolling interests	621	1,241	3,386	2,192
Comprehensive income (loss) attributable to the Partnership	$ 55,881	$ (9,041)	$ (3,425)	$ (30,041)

Condensed Consolidated Stateme7

Condensed Consolidated Statements of Changes in Partners' Capital and Noncontrolling Interests (Unaudited) - USD ($) $ in Thousands	Total	Delta House FPS LLC [Member]	Panther Asset Management LLC (Panther) [Member]	Series B [Member]	Parent [Member]	Parent [Member]Delta House FPS LLC [Member]	Parent [Member]Panther Asset Management LLC (Panther) [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interest [Member]	General Partner [Member]	General Partner [Member]Delta House FPS LLC [Member]	Limited Partner [Member]	Limited Partner [Member]Panther Asset Management LLC (Panther) [Member]
Partners' Capital at Dec. 31, 2015	$ 752,041			$ 33,593	$ 739,930			$ 40	$ 12,111	$ (47,091)		$ 753,388
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	(27,882)				(30,074)				2,192	(235)		(29,839)
Issuance of common units, net of offering costs	2,955				2,955							2,955
Cancellation of escrow units	(6,817)				(6,817)							(6,817)
Conversion of Series B units	0			(33,593)	0							33,593
Contributions	9,401				9,401					1,901		7,500
Distributions	(103,771)				(103,771)					(7,637)		(96,134)
Issuance of warrant	4,481				4,481					4,481		0
Contributions from noncontrolling interests owners	649								649
Contribution (distribution) for acquisition	990				990					990
LTIP vesting										(3,163)		3,163
Tax netting repurchase	(514)				(514)							(514)
Equity compensation expense	4,285				4,285					2,892		1,393
Post-retirement benefit plan	33				33			33
Addition of Mesquite noncontrolling interest	1,230								1,230
Acquisition of Gulf of Mexico Pipeline	1,831								1,831
Partners' Capital at Sep. 30, 2016	638,912			0	620,899			73	18,013	(47,862)		668,688
Partners' Capital at Dec. 31, 2016	585,157			0	568,402			(40)	16,755	(47,645)		616,087
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	(81)				(3,467)				3,386	(98)		(3,369)
Contributions	42,270				42,270					38,270		4,000
Distributions	(94,120)	$ (75,572)			(94,120)	$ (75,572)				(976)	$ (75,572)	(93,144)
Contributions from noncontrolling interests owners	296								296
Distributions to noncontrolling interests owners	(1,777)								(1,777)
Contribution (distribution) for acquisition			$ 12,532				$ 12,532						$ 12,532
Acquisition of noncontrolling interest (Note 3)	(28,298)				(23,653)				(4,645)			(23,653)
LTIP vesting										(4,633)		4,633
Tax netting repurchase	(1,642)				(1,642)							(1,642)
Equity compensation expense	6,067				6,067				0	4,430		1,637
Post-retirement benefit plan	42				42			42
Partners' Capital at Sep. 30, 2017	$ 444,874			$ 0	$ 430,859			$ 2	$ 14,015	$ (86,224)		$ 517,081

Condensed Consolidated Stateme8

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Cash flows from operating activities
Net income (loss)	$ (81)	$ (27,882)
Adjustments to reconcile net loss to net cash provided by operating activities including discontinued operations:
Depreciation, amortization and accretion	88,700	78,168
Amortization of deferred financing costs	3,610	2,328
Corporate overhead support from General Partner	4,000	7,500
Amortization of weather derivative premium	753	708
Unrealized loss on derivatives contracts, net	2,818	1,803
Non-cash compensation expense	6,067	4,285
Gain on MPOG acquisition (Note 3)	(32,383)	0
(Gain) loss on sale of assets and business, net of transaction costs of $2.5 million (Note 4)	(50,580)	2,247
Other non-cash items	1,842	(1,590)
Earnings in unconsolidated affiliates	(49,781)	(29,513)
Distributions from unconsolidated affiliates	49,781	29,513
Deferred tax expense	1,490	1,276
Changes in operating assets and liabilities, net of effects of acquisitions:
Accounts receivable	(4,172)	1,140
Inventory	(4,011)	(5,593)
Unbilled revenue	696	3,853
Risk management assets and liabilities	(974)	(1,030)
Other current assets	10,624	9,496
Other assets, net	(1,994)	772
Restricted cash	(3,135)	0
Accounts payable	(17,419)	(4,497)
Accrued gas purchases	8,805	1,904
Accrued expenses and other current liabilities	8,889	10,466
Asset retirement obligations	(603)	(598)
Other liabilities	426	(697)
Net cash provided by operating activities	23,368	84,059
Cash flows from investing activities
Acquisitions, net of cash acquired and settlements (Note 3)	(71,383)	(2,676)
Investments in unconsolidated affiliates (Note 10)	(49,828)	(114,007)
Additions to property, plant and equipment and other	(66,039)	(85,652)
Proceeds from sale of business and assets, net of cash on hand	167,979	11,761
Insurance proceeds from involuntary conversion of property, plant and equipment	150	0
Distributions from unconsolidated affiliates, return of capital	9,196	33,284
Restricted cash	302,736	(43,691)
Net cash provided by (used in) investing activities	292,811	(200,981)
Cash flows from financing activities
Proceeds from issuance of common units to public, net of offering costs	0	2,910
Distributions	(75,572)	0
Contributions	38,270	1,901
Distributions	(88,851)	(82,782)
Series C Units issuance cost	0	(62)
Acquisition of noncontrolling interests	0	1,831
Contribution from noncontrolling interest owners	296	649
Distributions to noncontrolling interests owners	(1,777)	0
LTIP tax netting unit repurchase	(1,642)	(514)
Payment of deferred financing costs	(2,234)	(3,987)
Proceeds from 3.77% Senior Notes	0	60,000
Proceeds from 3.77% Senior Notes	(1,351)	0
Payments of other debt	(3,732)	(2,769)
Payments of credit agreement	(546,408)	(172,650)
Borrowings on credit agreement	367,809	317,243
Other	86	(188)
Net cash provided by (used in) financing activities	(315,106)	121,582
Net increase in cash and cash equivalents	1,073	4,660
Cash and cash equivalents
Beginning of period	5,666	1,987
End of period	$ 6,739	$ 6,647

Condensed Consolidated Stateme9

Condensed Consolidated Statements of Cash Flows (Unaudited) (Parentheticals) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2017	Dec. 31, 2016	Sep. 30, 2016
Transaction costs	$ 2.5
3.77% Senior Notes [Member] | Senior Notes [Member]
Debt instrument, interest rate, stated percentage	3.77%	3.77%	3.77%

Organization, Basis of Presenta

Organization, Basis of Presentation and Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization, Basis of Presentation and Summary of Significant Accounting Policies	(1) Organization, Basis of Presentation and Summary of Significant Accounting Policies General American Midstream Partners, LP (the “Partnership”, “we”, “us”, or “our”) is a growth-oriented Delaware limited partnership that was formed on August 20, 2009 to own, operate, develop and acquire a diversified portfolio of midstream energy assets. The Partnership’s general partner, American Midstream GP, LLC (the “General Partner”), is 77% owned by High Point Infrastructure Partners, LLC (“HPIP”) and 23% indirectly owned by Magnolia Infrastructure Holdings, LLC, both of which are affiliates of ArcLight Capital Partners, LLC ("ArcLight"). Our capital accounts consist of notional General Partner units and units representing limited partner interests. JPE Acquisition On March 8, 2017, we completed the acquisition of JP Energy Partners LP (“JPE”), an entity controlled by ArcLight affiliates, in a unit-for-unit merger (“JPE Acquisition”). In connection with the transaction, we issued approximately 20.2 million common units to holders of the JPE common and subordinated units, including 9.8 million common units to ArcLight affiliates. In connection with the completion of the JPE Acquisition, we entered into a supplemental indenture pursuant to which the JPE Entities jointly and severally, fully and unconditionally, guarantee the 8.50% Senior Notes (as defined below). As both we and JPE were controlled by ArcLight affiliates, the acquisition represented a transaction among entities under common control. Although we are the legal acquirer, JPE was considered the acquirer for accounting purposes as ArcLight obtained control of JPE prior to obtaining control of us on April 15, 2013. As a result, we adjusted our historical financial statements to reflect ArcLight’s acquisition cost basis of their investment in us back to April 15, 2013. In addition, the accompanying financial statements and related notes have been retrospectively adjusted to include the historical results of JPE prior to the effective date of the JPE Acquisition. The accompanying financial statements and related notes present the combined financial position, results of operations, cash flows and equity of JPE at historical cost. Disposition of Propane Business On September 1, 2017, we completed the disposition of our Propane Marketing Services business the ("Propane Business") pursuant to the Membership Interest Purchase Agreement dated July 21, 2017, between AMID Merger LP, a wholly owned subsidiary of the Partnership, and SHV Energy N.V. As a result of the disposition of our Propane Business, we classified the results of operations of the Propane Business as discontinued operations. See Note 4 - Discontinued Operations. Nature of business We provide critical midstream infrastructure that links producers of natural gas, crude oil, NGLs, condensate and specialty chemicals to numerous intermediate and end-use markets. Through our five reportable segments, (1) gas gathering and processing services, (2) liquid pipelines and services, (3) natural gas transportation services, (4) offshore pipelines and services and (5) terminalling services, we engage 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; storing specialty chemical products and selling refined products. Most of our cash flow is generated from fee-based and fixed-margin arrangements for gathering, processing, transporting and treating natural gas and crude oil, firm capacity reservation charges, interruptible transportation charges, guaranteed firm storage contracts, throughput fees and other optional charges associated with ancillary services. Our primary assets are strategically located in some of the most prolific onshore and offshore producing regions and key demand markets in the United States. Our gathering and processing assets are primarily located in (i) the Permian Basin of West Texas, (ii) the Cotton Valley/Haynesville Shale of East Texas, (iii) the Eagle Ford Shale of South Texas, (iv) the Bakken Shale of North Dakota, and (v) offshore in the Gulf of Mexico. Our natural gas transportation, offshore pipelines and terminal assets are in key demand markets in Alabama, Arkansas, Louisiana, Mississippi and Tennessee and in the Port of New Orleans in Louisiana and the Port of Brunswick in Georgia. Basis of presentation The financial statements and supplementary data, management’s discussion and analysis of financial condition and results of operations and certain selected financial data in our Form 10-K for the year ended December 31, 2016 (the “Annual Report”), as filed with the U.S. Securities and Exchange Commission (the “SEC”) on March 28, 2017, were recast by the Current Report on Form 8-K, dated September 18, 2017 (“Recast Form 8-K”). There have been no revisions or updates to any other sections of the Annual Report other than the revisions noted above. The unaudited financial information included in this Quarterly Report has been prepared on the same basis as the audited consolidated financial statements included in the Recast Form 8-K, and recast to retrospectively reflect the change in classification of the Propane Business to discontinued operations for all periods presented. The results of operations for the three and nine months ended September 30, 2017 are not necessarily indicative of results expected for the full year. In the opinion of our management, such financial information reflects all adjustments necessary for a fair statement of the financial position and the results of operations for such interim periods in accordance with GAAP. All such adjustments are of a normal recurring nature. All intercompany items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC. Transactions between entities under common control We have entered, and may enter, into transactions with ArcLight affiliates whereby we receive midstream assets or other businesses in exchange for cash or Partnership equity. We account for the net assets acquired at the affiliate's historical cost basis as the transactions are between entities under common control. In certain cases, our historical financial statements were revised to include the results attributable to the assets acquired from the later of June 2011 (the date Arclight affiliates obtained control of JPE) or the date the ArcLight affiliate obtained control of the assets acquired. Summary of Significant Accounting Policies Use of estimates When preparing 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. Cash, cash equivalents and restricted cash We consider all highly liquid investments with an original maturity of three months or less at the date of purchase to be cash equivalents. The carrying value of cash and cash equivalents approximates fair value because of the short term to maturity of these investments. From time to time we are required to maintain cash in separate accounts the use of which is restricted by the terms of our debt agreements, asset retirement obligations and contracted arrangements. Such amounts are included in Restricted cash in our unaudited condensed consolidated balance sheets. Allowance for doubtful accounts We establish provisions for losses on accounts receivable when we determine that we will not collect all or part of an outstanding balance. Collectability is reviewed regularly and an allowance is established or adjusted, as necessary, using the specific identification method, historical collection experience and the age of accounts receivable. Investments in unconsolidated affiliates We hold membership interests in entities that own and operate natural gas pipeline systems and NGL and crude oil pipelines in and around Louisiana, Alabama, Mississippi and the Gulf of Mexico. While we have significant influence over these entities, we do not control them and therefore, they are accounted for using the equity method and are reported in Investment in unconsolidated affiliates in the condensed consolidated balance sheets. We evaluate the recoverability of these investments on a regular basis and recognize impairment write downs if we determine a loss in value represents an other-than-temporary-decline. The unconsolidated affiliates that were determined to be variable interest entities (“VIE”) due to disproportionate economic interests and decision making rights were further evaluated under the VIE method of consolidation. In each case, we lack the power to direct the activities that most significantly impact the unconsolidated affiliate’s economic performance. Therefore, as we do not hold a controlling financial interest in these affiliates, we account for our related investments using the equity method. Additionally, our maximum exposure to loss related to each entity is limited to our equity investment as presented on the condensed consolidated balance sheets as of the balance sheet date. In each case, we are not obligated to absorb losses greater than our proportional ownership percentages. Our right to receive residual returns is not limited to any amount less than the ownership percentages. We also have a joint venture arrangement in which we and our partners share proportional ownership and responsibilities and receive returns in accordance with our ownership percentage. Revenue recognition We recognize revenue from the sale of commodities (e.g., natural gas, crude oil, NGLs, refined products or condensate) as well as from the provision of gathering, processing, transportation or storage services when all of the following criteria are met: i) persuasive evidence of an exchange arrangement exists, ii) delivery has occurred or services have been rendered, iii) the price is fixed or determinable, and iv) collectability is reasonably assured. We recognize revenue from the sale of commodities and the related cost of product sold on a gross basis for those transactions where we act as the principal and take title to commodities that are purchased for resale. Revenue-related taxes collected from customers and remitted to taxing authorities, principally sales taxes, are presented on a net basis within the unaudited condensed consolidated statements of operations.

New Accounting Pronouncements (

New Accounting Pronouncements (Notes)	9 Months Ended
	Sep. 30, 2017
Accounting Policies [Abstract]
New Accounting Pronouncements	(2) New Accounting Pronouncements Accounting Standards Issued Not Yet Adopted In May 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-09, “ Revenue from Contracts with Customers (Topic 606)” , which amends the existing accounting guidance for revenue recognition. The update 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 No. 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. From March 2016 to May 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; ASU No. 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 and ASU No. 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. We are in the process of reviewing our various customer arrangements in order to determine the impact the new accounting guidance for revenue recognition will have on our consolidated financial statements and related disclosures. We also have engaged a third-party consulting firm to assist us with all the three phases of adoption of the new guidance (Impact Assessment, Convert and Implement). We are currently in the Convert phase and revenue streams have been determined. Certain preliminary testing has been performed to validate such streams. We will adopt the new standard on its effective date January 1, 2018 using the modified retrospective method of adoption. In February 2016, the FASB issued ASU No. 2016-02 (Topic 842) " Leases ", which supersedes the lease recognition requirements in ASC Topic 840, "Leases". Under ASU No. 2016-02 lessees are required to recognize assets and liabilities on the balance sheet for most leases and provide enhanced disclosures. Leases will continue to be classified as either finance or operating. ASU No. 2016-02 is effective for annual reporting periods, and interim periods within those years beginning after December 15, 2018. Entities are required to use a modified retrospective approach for leases that exist or are entered into after the beginning of the earliest comparative period in the financial statements, and there are certain optional practical expedients that an entity may elect to apply. Full retrospective application is prohibited and early adoption by public entities is permitted. We are in the process of evaluating the impact of ASU 2016-02 on our consolidated financial statements as we will be required to reflect our various lease obligations and associated asset use rights on our consolidated balance sheets. The adoption may also impact our debt covenant compliance and may require us to modify or replace certain of our existing information systems. We will adopt the guidance on its effective date January 1, 2019. In August 2016, the FASB issued ASU No. 2016-15, “ Statement of Cash Flows (Topic 320): Classification of Cash Receipts and Cash Payments” , which addresses eight specific cash flow issues with the objective of reducing the existing diversity of presentation and classification in the statement of cash flows. ASU No. 2016-15 is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal periods. The retrospective transition method of adoption is required unless it is impracticable. Early adoption is permitted, but only if all aspects are adopted in the same period. We are still evaluating the impact of this update on our consolidated statements of cash flows and the related disclosures. We will adopt the standard upon its effective date January 1, 2018. In November 2016, the FASB issued ASU No. 2016-18, “ Statement of Cash Flows (Topic 230): Restricted Cash” , which aims to improve the disclosure of the change during the period in total cash, cash equivalents and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash or restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts on the statement of cash flows. The update is effective beginning first quarter of 2018. Early adoption is permitted, but it must occur in the first interim period. Any adjustments required in early adoption of this update should be reflected as of the beginning of the fiscal year that includes the interim period and should be applied using a retrospective transition method to each period. We will adopt the standard on its effective date of January 1, 2018. In January 2017, the FASB issued ASU No. 2017-01 , “Business Combinations (Topic 805): Clarifying the Definition of a Business”. The guidance provides criteria for use in determining when to conclude an integrated “set of assets and activities (as defined in the original guidance) being acquired or disposed in a transaction is not a business. Where the criteria are not met, more stringent screening has been provided to define a set as a business without an output, as more narrowly defined within the guidance. ASU No. 2017-01 is effective for annual periods beginning after December 15, 2017, including interim periods within those periods. The amendments should be applied prospectively on or after the effective date. Early adoption is permitted. We are still in the process of evaluating the guidance and can not determine the impact of this guidance on our consolidated financial statements and related disclosures. We will adopt ASU 2017-01 on its effective date of January 1, 2018. In January 2017, the FASB issued ASU No. 2017-04 , “Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment” , in which the guidance on testing for goodwill was updated by the elimination of Step 2 in the determination on whether goodwill should be considered impaired. The annual and/or interim assessments are still required to be completed. Further, the guidance eliminates the requirement to assess reporting units with zero or negative carrying values, however, the carrying values for all reporting units must be disclosed. ASU No. 2017-04 is effective for annual or any interim goodwill impairment tests beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. We elected to early adopt the guidance in connection with our annual assessment to be performed in October 2017 using the required prospective method. In May 2017, the FASB issued ASU No. 2017-09 , “Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting” , to provide guidance about which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting. Pursuant to this ASU, an entity should account for the effects of a modification unless all the following are met: (1) the fair value (or calculated value or intrinsic value, if such an alternative measurement method is used) of the modified award is the same as the fair value (or calculated value or intrinsic value, if such an alternative measurement method is used) of the original award immediately before the original award is modified (if the modification does not affect any of the inputs to the valuation technique that the entity uses to value the award, the entity is not required to estimate the value immediately before and after the modification); (2) the vesting conditions of the modified award are the same as the vesting conditions of the original award immediately before the original award is modified; and (3) the classification of the modified award as an equity instrument or a liability instrument is the same as the classification of the original award immediately before the original award is modified. ASU No. 2017-09 is effective for annual periods beginning after December 15, 2017, including interim periods within those periods. Early adoption is permitted, including adoption in any interim period. This update should be applied prospectively to an award modified on or after the adoption date. We do not believe that the impact of this update on our consolidated financial statements and related disclosures will be material and will adopt the guidance on its effective date January 1, 2018.

Acquisitions

Acquisitions	9 Months Ended
	Sep. 30, 2017
Business Combinations [Abstract]
Acquisitions	(3) Acquisitions JP Energy Partners LP On March 8, 2017, we completed the acquisition of JPE, a legal entity controlled by ArcLight affiliates, in a unit-for-unit merger. In connection with the transaction, each JPE common or subordinated unit held by investors not affiliated with ArcLight was converted into the right to receive 0.5775 of a Partnership common unit, and each JPE common or subordinated unit held by ArcLight affiliates was converted into the right to receive 0.5225 of a Partnership common unit. We issued a total of 20.2 million of common units to complete the acquisition, including 9.8 million common units to ArcLight affiliates. As both we and JPE were controlled by ArcLight affiliates, the acquisition represented a transaction among entities under common control. Although we were the legal acquirer, JPE was considered the acquirer for accounting purposes as ArcLight obtained control of JPE prior to obtaining control of us on April 15, 2013. As a result, we adjusted our historical financial statements to reflect ArcLight’s acquisition cost basis of us back to April 15, 2013. In addition, the accompanying financial statements and related notes have been retrospectively adjusted to include the historical results of JPE prior to the effective date of the JPE acquisition. The accompanying financial statements and related notes present the combined financial position, results of operations, cash flows and equity of JPE at historical cost. JPE owns, operates and develops a diversified portfolio of midstream energy assets which provide midstream infrastructure solutions for the growing supply of crude oil, refined products and NGLs, in the United States. Viosca Knoll On June 2, 2017, we acquired 100% of the Viosca Knoll System (“Viosca Knoll”) from Genesis Energy, L.P. for total consideration of approximately $32 million in cash and have accounted for this acquisition as a business combination. The Viosca Knoll System serves producing fields located in the Main Pass, Mississippi Canyon and Viosca Knoll areas of the Gulf of Mexico and connects to several major delivery pipelines including the Partnership’s High Point and Destin pipelines. Viosca Knoll will provide greater East-West Gulf connectivity, through the connection of the High Point Gas Transmission system and the Destin Pipeline, both controlled by us. The Viosca Knoll acquisition was funded with the borrowings under the Partnership’s revolving credit facility, and Viosca Knoll was added to our Offshore pipeline and services segment. The following table presents our aggregated allocation of the purchase price based on estimated fair values of assets and liabilities acquired (in thousands): As of September 30, 2017 Purchase Price Allocation Property, plant and equipment: Pipelines and right-of-way $ 13,433 Equipment 18,853 Total property, plant and equipment 32,286 Liability (286 ) Total cash consideration $ 32,000 The purchase price allocation is subject to the measurement period that ends at the earlier of twelve months from the date of acquisition or when all information becomes available. We have reallocated approximately $3.3 million from Intangibles to Property, plant and equipment since the initial purchase price allocation disclosed in the second quarter of 2017. Panther On August 8, 2017, the Partnership acquired 100% of the interest in Panther Offshore Gathering Systems, LLC (“POGS”), Panther Pipeline, LLC (“PPL”) and Panther Operating Company, LLC (“POC”) from Panther Asset Management LLC (“Panther”) for approximately $57.2 million . The consideration included $39.1 million cash, funded from borrowings under the Partnership’s revolving credit facility, and common units representing limited partner interests in the Partnership, valued at $12.5 million based on unit value as of the acquisition date. Panther owns and operates more than 1,000 miles of oil and gas pipelines, primarily in Texas and Louisiana offshore state and federal waters. The underlying acquired assets are highly complementary to the Partnership’s core Gulf of Mexico assets as a substantial portion of Panther’s cash flows are generated by our joint ventures. As part of the purchase of POGS, we acquired the outstanding interests in one of our equity investments, Main Pass Oil Gathering (“MPOG”), as well as the remaining equity interest in our consolidated subsidiary, American Panther, LLC (“AmPan”). As such, the Partnership now owns 100% of MPOG and AmPan. We determined that the acquisition of the remaining interest in MPOG on August 8, 2017 resulted in a change in control and MPOG has been consolidated from the acquisition date. The effect was the Partnership’s previously held equity interest in MPOG was remeasured to fair value and the excess (approximately $32.3 million ) of fair value over historical carrying value was recognized as a gain in Other income (expense) on the unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2017. For AmPan, which has historically been consolidated by the Partnership, the acquisition of Panther’s remaining interest resulted in the acquisition of a noncontrolling interest. Accordingly the excess of the fair value of the acquired interest (approximately $28.3 million ) over the carrying value of the noncontrolling interest (approximately $4.6 million ) has been reported as a distribution to unitholders. PPL owns a 50% undivided ownership interest in the Matagorda and the Brazoria County Gas systems which will be proportionally consolidated from the acquisition date. POC operates pipeline assets on behalf of both third parties and affiliates of the Partnership for a fee and will be fully consolidated by the Partnership. The following table presents the aggregated preliminary allocation of the purchase price based on estimated fair values of Panther’s assets acquired and liabilities assumed (in thousands): Purchase Price Allocation Fair value of acquired noncontrolling interest $ 28,298 Property, plant and equipment 16,870 Intangibles (customer relationships) 9,989 Net working capital, net of cash acquired 2,410 Other 2,975 Asset retirement obligation $ (3,367 ) Total consideration $ 57,175 The purchase price allocation is subject to the measurement period that ends at the earlier of twelve months from the acquisition date or when all information becomes available. The pro forma effect of our business acquisitions was immaterial to our unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2017 and the comparative periods, respectively, and therefore is not separately disclosed.

Discontinued Operations (Notes)

Discontinued Operations (Notes)	9 Months Ended
	Sep. 30, 2017
Discontinued Operations and Disposal Groups [Abstract]
Discontinued Operations	(4) Discontinued Operations Disposition of Propane Business On September 1, 2017, we completed the disposition of the Propane Business pursuant to the Membership Interest Purchase Agreement dated July 21, 2017, between AMID Merger LP, a wholly owned subsidiary of the Partnership, and SHV Energy N.V. Through the transaction, we divested 100% of our Propane Business, including Pinnacle Propane’s 40 service locations; Pinnacle Propane Express’ cylinder exchange business and related logistic assets; and the Alliant Gas utility system. Prior to the sale, we moved the trucking business from the Propane Marketing Services segment to the Liquid Pipelines and Services segment. With the disposition of the Propane Business, we eliminated the Propane Marketing Services segment. In connection with the transaction, we received approximately $170 million in cash, net of customary closing adjustments, and recorded a gain of approximately $46.5 million , net of $2.5 million of transaction costs. We have reported the results of our Propane Business, including the gain on sale, as discontinued operations in our unaudited condensed consolidated statements of operations for all periods presented. The following tables summarize the financial information related to the Propane Business for the periods presented, as required by ASC 420 - Discontinued Operations . Unaudited Condensed Consolidated Balance Sheet of the discontinued operation Propane Business (in thousands) December 31, 2016 Total current assets of discontinued operations $ 22,727 Total noncurrent assets of discontinued operations 114,032 Total assets of discontinued operations $ 136,759 Total current liabilities of discontinued operations $ 14,319 Other long-term liabilities of discontinued operations 172 Total liabilities of discontinued operations $ 14,491 Unaudited Condensed Consolidated Statements of Operations of the discontinued operation Propane Business (in thousands) Three months ended September 30, Nine months ended September 30, 2017 2016 2017 2016 (1) Total revenue $ 20,458 $ 27,756 $ 87,615 $ 103,718 Total operating expenses 22,489 30,158 92,196 96,003 Income (loss) from discontinued operations before taxes (1,834 ) (2,310 ) (4,301 ) 8,069 Income tax benefit (expense) (15 ) — (59 ) 2 Income (loss) from discontinued operations (1,849 ) (2,310 ) (4,360 ) 8,071 Gain from the sale of discontinued operations 46,545 — 46,545 — Partnership’s income (loss) from discontinued operations, including gain on sale. $ 44,696 $ (2,310 ) $ 42,185 $ 8,071 _____________________________________ (1) Amounts for the nine months ended September 30, 2016 do not included the results of certain trucking and marketing assets of JPE in the Mid-Continent area (the “Mid Continent Business”), which were sold in the first quarter of 2016 and are classified as discontinued operations. The total revenue, total operating expenses and loss from discontinued operations related to the Mid Continent Business for the nine months ended September 30, 2016 were $11.5 million , $12.0 million and $0.5 million respectively. Other selected unaudited financial information related to the Propane Business (in thousands) Three months ended September 30, Nine months ended September 30, 2017 2016 2017 2016 Depreciation and amortization $ 2,355 $ 3,850 $ 9,823 $ 12,020 Capital expenditures 722 1,483 3,143 3,451 Other operating and investing non-cash items related to discontinued operations: (Gain) loss on sales of assets, net 118 725 (55 ) 2,064 Unrealized (gain) loss on derivatives contracts, net (526 ) 106 530 (628 )

Inventory (Notes)

Inventory (Notes)	9 Months Ended
	Sep. 30, 2017
Inventory Disclosure [Abstract]
Inventory	(5) Inventory Inventory consists of the following (in thousands): September 30, 2017 December 31, 2016 Crude oil $ 4,565 $ 1,216 NGLs 232 288 Refined products 674 — Materials, supplies and equipment 499 486 Total inventory $ 5,970 $ 1,990

Other Current Assets

Other Current Assets	9 Months Ended
	Sep. 30, 2017
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Other Current Assets	(6) Other Current Assets Other current assets consist of the following (in thousands): September 30, 2017 December 31, 2016 Prepaid insurance $ 1,428 $ 9,702 Insurance receivables 3,728 1,624 Due from related parties 5,062 4,833 Other receivables 2,768 2,997 Risk management assets 1,827 469 Other assets 2,331 5,891 Total other current assets $ 17,144 $ 25,516

Risk Management Activities

Risk Management Activities	9 Months Ended
	Sep. 30, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Risk Management Activities	(7) Risk Management Activities We are exposed to certain market risks related to the volatility of commodity prices and changes in interest rates. To monitor and manage these market risks, we have established comprehensive risk management policies and procedures. We do not enter into derivative instruments for any purpose other than hedging commodity price risk, interest rate risk, and weather risk. We do not speculate using derivative instruments. Commodity Derivatives To manage the impact of the risks associated with changes in the market price of NGL purchases, crude oil, refined products and natural gas in our day-to-day business, we used a combination of fixed price swap and forward contracts. Our forward contracts that qualify for the Normal Purchase Normal Sale (“NPNS”) exception under GAAP are recognized when the underlying physical transaction is delivered . In accordance with ASC 815, Derivatives and Hedging, if it is determined that a transaction designated as NPNS no longer meets the scope exception, the fair value of the related contract is recorded on the balance sheet (as an asset or liability) and the difference between the fair value and the contract amount is immediately recognized through earnings. We measure our commodity derivatives at fair value using the income approach which discounts the future net cash settlements expected under the derivative contracts to a present value. These valuations utilize indirectly observable (“Level 2”) inputs, including contractual terms and commodity prices observable at commonly quoted intervals. The following table summarizes the net notional volumes of our outstanding commodity-related derivatives, excluding those contracts that qualified for the NPNS exception as of September 30, 2017 and December 31, 2016, none of which were designated as hedges for accounting purposes. September 30, 2017 December 31, 2016 Commodity Swaps Volume Maturity Volume Maturity NGLs Fixed Price (gallons) 819,000 January 8, 2018 Crude Oil Fixed Price (barrels) 125,000 October 6, 2017 - December 7, 2017 — — Crude Oil Basis (barrels) — — 180,000 January 25, 2017- March 25, 2017 Interest Rate Swaps To manage the impact of the interest rate risk associated with our Credit Agreement, as defined in Note 13 - Debt Obligations , 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 September 30, 2017 and December 31, 2016, we had a combined notional principal amount of $650.0 million of variable to fixed interest rate swap agreements. As of September 30, 2017, the maximum length of time over which we have hedged a portion of our exposure due to interest rate risk is through December 31, 2022. The fair value of our interest rate swaps was estimated using a valuation methodology based upon forward interest rates and 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, which represent Level 2 inputs in the valuation hierarchy, are obtained from independent pricing services and we have made no adjustments to those prices. Weather Derivative In the second quarter of 2017, we entered into a yearly weather derivative arrangement 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 of certain strength passes through the areas identified in the derivative agreement. The weather derivative, which is accounted for using the intrinsic value method, was entered into with a single counterparty, and we were not required to post collateral. We paid $1.1 million and $1.0 million in premiums during the nine months ended September 30, 2017 and 2016 , respectively. Premiums are amortized to Direct operating expenses on a straight-line basis over the one year term of the contract. Unamortized amounts associated with the weather derivatives were approximately $0.8 million and $0.4 million as of September 30, 2017 and December 31, 2016 , respectively, and are included in Other current assets on the unaudited condensed consolidated balance sheets. The following table summarizes the fair values of our derivative contracts (before netting adjustments) included in the condensed consolidated balance sheets (in thousands): Asset Derivatives Liability Derivatives Type Balance Sheet Classification September 30, December 31, 2016 September 30, December 31, 2016 Commodity swaps Other current assets $ 267 $ 112 $ — $ — Commodity swaps Accrued expenses and other current liabilities — — (653 ) (1 ) Commodity swaps Other liabilities — — — (1 ) Interest rate swaps Other current assets 1,041 Interest rate swaps Risk management assets (long-term) 7,545 10,628 — — Interest rate swaps Accrued expenses and other current liabilities — — — (252 ) Weather derivatives Other current assets $ 786 $ 429 $ — $ — Total $ 9,639 $ 11,169 $ (653 ) $ (254 ) The following tables present the fair value of our recognized derivative assets and liabilities on a gross basis and amounts offset in the condensed consolidated balance sheets that are subject to enforceable master netting arrangements (in thousands): Gross Risk Management Position Netting Adjustments Net Risk Management Position Balance Sheet Classification September 30, December 31, 2016 September 30, December 31, 2016 September 30, December 31, 2016 Other current assets $ 2,094 $ 541 $ (267 ) $ (72 ) $ 1,827 $ 469 Risk management assets- long term 7,545 10,628 — (1 ) 7,545 10,627 Total assets $ 9,639 $ 11,169 $ (267 ) $ (73 ) $ 9,372 $ 11,096 Accrued expenses and other liabilities $ (653 ) $ (253 ) $ 267 $ 72 $ (386 ) $ (181 ) Other liabilities — (1 ) — 1 — — Total liabilities $ (653 ) $ (254 ) $ 267 $ 73 $ (386 ) $ (181 ) For each of the three and nine months ended September 30, 2017 and 2016 the realized and unrealized gains (losses) associated with our commodity, interest rate and weather derivative instruments were recorded in our unaudited condensed consolidated statements of operations as follows (in thousands): Three months ended September 30, Nine months ended September 30, Statement of Operations Classification Realized Unrealized Realized Unrealized 2017 Gains (losses) on commodity derivatives, net $ (51 ) $ (546 ) $ 465 $ (498 ) Interest expense 51 221 (19 ) (1,790 ) Direct operating expenses (278 ) — (753 ) — Total $ (278 ) $ (325 ) $ (307 ) $ (2,288 ) 2016 Gains (losses) on commodity derivatives, net $ (742 ) $ 1,066 $ (1,432 ) $ (497 ) Interest expense (75 ) 2,109 (106 ) (1,934 ) Direct operating expenses (257 ) — (708 ) — Total $ (1,074 ) $ 3,175 $ (2,246 ) $ (2,431 )

Property, Plant and Equipment

Property, Plant and Equipment	9 Months Ended
	Sep. 30, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	(8) Property, Plant and Equipment Property, plant and equipment, net, consists of the following (in thousands): Useful Life (in years) September 30, December 31, Land Infinite $ 18,440 $ 18,861 Construction in progress N/A 81,133 128,519 Buildings and improvements 4 to 40 13,782 13,762 Transportation equipment 5 to 15 22,743 20,010 Processing and treating plants 8 to 40 141,334 120,977 Pipelines, compressors and right-of-way 3 to 40 958,004 804,815 Storage 3 to 40 146,473 146,408 Equipment 3 to 31 79,567 77,978 Total property, plant and equipment 1,461,476 1,331,330 Accumulated depreciation (320,650 ) (264,722 ) Property, plant and equipment, net $ 1,140,826 $ 1,066,608 At September 30, 2017 and December 31, 2016 , gross property, plant and equipment included $314.8 million and $291.1 million , respectively, related to our FERC regulated interstate and intrastate assets. Depreciation expense totaled $20.1 million and $17.8 million for the three months ended September 30, 2017 and 2016 , respectively, and $56.9 million and $51.6 million for the nine months ended September 30, 2017 and 2016 , respectively. Capitalized interest was $0.5 million and $0.7 million for each of the three months ended September 30, 2017 and 2016 , respectively and $2.0 million and $1.7 million for the nine months ended September 30, 2017 and 2016 , respectively.

Goodwill and Intangible Assets

Goodwill and Intangible Assets	9 Months Ended
	Sep. 30, 2017
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	(9) Goodwill and Intangible Assets Goodwill consists of the following (in thousands): September 30, 2017 December 31, 2016 Liquid Pipelines and Services $ 113,671 $ 113,671 Terminalling Services 88,464 88,464 Total $ 202,135 $ 202,135 Intangible assets, net, consists of customer relationships, dedicated acreage agreements, collaborative arrangements, noncompete agreements and trade names. These intangible assets have definite lives and are subject to amortization on a straight-line basis over their economic lives, currently ranging from approximately 5 years to 44 years . Intangible assets, net, consist of the following (in thousands): September 30, 2017 Gross carrying amount Accumulated amortization Net carrying amount Customer relationships $ 116,345 $ (28,088 ) $ 88,257 Customer contracts 94,693 (46,927 ) 47,766 Dedicated acreage 53,350 (5,773 ) 47,577 Collaborative arrangements 11,884 (1,203 ) 10,681 Noncompete agreements 1,064 (1,064 ) — Other 198 (23 ) 175 Total $ 277,534 $ (83,078 ) $ 194,456 December 31, 2016 Gross carrying amount Accumulated amortization Net carrying amount Customer relationships $ 106,417 $ (23,245 ) $ 83,172 Customer contracts 94,692 (33,228 ) 61,464 Dedicated acreage 53,350 (4,439 ) 48,911 Collaborative arrangements 11,884 (601 ) 11,283 Noncompete agreements 1,063 (1,000 ) 63 Other 198 (20 ) 178 Total $ 267,604 $ (62,533 ) $ 205,071 Amortization expense related to our intangible assets totaled $5.1 million and $4.4 million for the three months ended September 30, 2017 and 2016 , respectively, and $20.6 million and $13.3 million for the nine months ended September 30, 2017 and 2016 , respectively.

Investment in Unconsolidated Af

Investment in Unconsolidated Affiliates	9 Months Ended
	Sep. 30, 2017
Equity Method Investments and Joint Ventures [Abstract]
Investment in Unconsolidated Affiliates	(10) Investments in unconsolidated affiliates Joint Venture with Targa Midstream Services, LLC On August 8, 2017, we entered into a joint venture agreement with Targa Midstream Services, LLC (“Targa”) by which our previously wholly owned subsidiary Cayenne Pipeline, LLC (“Cayenne”) became the Cayenne joint venture between Targa and us (“Cayenne JV”). We received $5.0 million in cash in exchange for the sale of 50% ownership interest in Cayenne to Targa. The sole asset of the joint venture is a natural gas pipeline which is being converted into a natural gas liquids pipeline. Both parties will each have 50% economic interests and 50% voting rights, with Targa serving as the operator of the pipeline and the joint venture. The additional costs of conversion and associated construction are shared equally by us and Targa. By the end of the fourth quarter of 2017, the pipeline is expected to be operational. Acquisition of additional ownership interest in Delta House On September 29, 2017, we acquired an additional 15.5% equity interest in Class A units of Delta House FPS LLC (“FPS”) and Delta House Oil and Gas Lateral LLC (“Lateral”) (collectively referred to as “Delta House”), from affiliates of ArcLight for total cash consideration of approximately $125.4 million . FPS operates a semi-submersible floating production and processing system in the Gulf of Mexico. Lateral operates oil and natural gas lateral transportation facilities that receive and transport production from the FPS floating production system. Post-closing, the Partnership and ArcLight indirectly own a 35.7% and 23.3% interest, respectively, in Delta House. As our 15.5% interest in Delta House was previously owned directly by ArcLight, we have accounted for our investment at our affiliate's carry-over basis resulting in $49.8 million recorded in Investments in unconsolidated affiliates in our unaudited condensed consolidated balance sheets, and as an investing activity within the related unaudited condensed consolidated statements of cash flows. The amount by which the total consideration exceeded the carry-over basis was $75.6 million and was recorded as a distribution to our general partner within the unaudited condensed consolidated statements of changes in partners’ capital and noncontrolling interests and a financing activity in the unaudited condensed consolidated statements of cash flows. For the three and nine months ended September 30, 2017, the Partnership recorded $12.5 million and $34.6 million , respectively, in equity earnings from Delta House. The Partnership also received cash distributions of $ 10.3 million and $26.2 million for the three and nine months ended September 30, 2017, respectively. The excess of the cash distributions received over the earnings recorded from Delta House is classified as a return of capital within cash flows from investing activities in our condensed consolidated statements of cash flows. The following table presents the activity in our equity method investments in unconsolidated affiliates (in thousands): Delta House (1) Emerald Transactions (2) FPS OGL Destin Tri-States Okeanos Wilprise MPOG (4) Cayenne JV (3) Total Ownership % - 12/31/2016 20.1 % 20.1 % 49.7 % 16.7 % 66.7 % 25.3% 66.7% - Ownership % - 9/30/2017 35.7 % 35.7 % 49.7 % 16.7 % 66.7 % 25.3% - 50.0 % Balances at December 31, 2016 $ 64,483 $ 25,450 $ 110,882 $ 55,022 $ 27,059 $ 4,944 $ 4,147 $ — $ 291,987 Acquisitions 22,539 27,289 — — — — (2,363 ) — 47,465 Earnings in unconsolidated affiliates 23,994 10,589 6,243 3,394 5,706 493 (683 ) 45 49,781 Contributions — — — — — — — 3,770 3,770 Distributions (13,990 ) (12,183 ) (17,334 ) (4,359 ) (9,333 ) (677 ) (1,101 ) — (58,977 ) Balances at September 30, 2017 $ 97,026 $ 51,145 $ 99,791 $ 54,057 $ 23,432 $ 4,760 $ — $ 3,815 $ 334,026 ___________________________________________________ (1) Represents direct and indirect ownership interests in Class A units and common units. (2) Represents our Emerald equity method investments which were acquired in the second quarter of 2016. (3) We formed Cayenne JV effective August 8, 2017. (4) Beginning August 8, 2017, the Partnership consolidated MPOG. See Note 3 - Acquisitions. The following tables present the summarized combined financial information for our equity investments (amounts represent 100% of investee financial information) (in thousands): Balance Sheets (1) : September 30, 2017 December 31, 2016 Current assets $ 100,400 $ 120,167 Non-current assets 1,294,333 1,369,492 Current liabilities 139,217 133,085 Non-current liabilities $ 422,988 $ 541,312 Three months ended September 30, Nine months ended September 30, Statements of Operations (1) : 2017 2016 2017 2016 Revenue $ 104,904 $ 93,440 $ 304,801 $ 278,720 Gross profit 97,636 83,350 280,996 253,447 Net income $ 77,238 $ 62,775 $ 222,005 $ 199,591 _____________________________________ (1) MPOG was consolidated by us as of August 8, 2017, therefore the tables above do not include MPOG as of September 30, 2017 and for the three and nine months ended September 30, 2017.

Accrued Expenses and Other Curr

Accrued Expenses and Other Current Liabilities	9 Months Ended
	Sep. 30, 2017
Other Liabilities Disclosure [Abstract]
Accrued Expenses and Other Current Liabilities	(11) Accrued Expenses and Other Current Liabilities Accrued expenses and other current liabilities consists of the following (in thousands): September 30, 2017 December 31, 2016 Accrued interest $ 9,973 $ 5,743 Taxes payable 7,052 1,186 Current portion of asset retirement obligation 6,416 6,499 Additional Blackwater acquisition consideration 5,000 5,000 Due to related parties 5,115 4,072 Royalties payable 3,548 3,926 Convertible preferred unit distributions 2,871 7,103 Legal accrual 2,783 — Capital expenditures 4,032 14,274 Accrued operating expenses 2,938 — Gas imbalances payable 1,860 1,098 Customer deposits 1,537 148 Employee compensation 1,505 8,438 Transaction costs 736 3,000 Other 12,139 12,234 Total accrued expenses and other current liabilities $ 67,505 $ 72,721

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	(12) Asset Retirement Obligations We record a liability for the fair value of asset retirement obligations and conditional asset retirement obligations (collectively referred to as “AROs”) that we can reasonably estimate, on a discounted basis, in the period in which the liability is incurred. Generally, the fair value of the liability is calculated using discounted cash flow techniques and based on internal estimates and assumptions related to (i) future retirement costs, (ii) future inflation rates, and (iii) credit-adjusted risk-free interest rates. Significant increases or decreases in the assumptions would result in a significant change to the fair value measurement. Certain assets related to our Offshore Pipelines and Services segment have regulatory obligations to perform remediation, and in some instances, dismantlement and removal activities when the assets are abandoned. These AROs 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, however, we do not believe that such demand will cease for the foreseeable future. The majority of the current portion of our AROs is related to the retirement of the Midla pipeline discussed in Note 18 - Commitments and Contingencies . The following table presents activity in our asset retirement obligations for the nine months ended September 30, 2017 (in thousands): Non-current balance $ 44,363 Current balance 6,499 Balances at December 31, 2016 $ 50,862 Additions 6,805 Expenditures (697 ) Accretion expense 1,492 Balances at September 30, 2017 $ 58,462 Less: current portion 6,416 Noncurrent asset retirement obligation $ 52,046 ___________________________________________________ We are required to establish security against potential obligations relating to the abandonment of certain transmission assets that may be imposed on the previous owner by applicable regulatory authorities. We have deposited $5.0 million with a third party to secure our performance on these potential obligations. These deposits are included in Restricted cash-long term in our unaudited condensed consolidated balance sheets as of September 30, 2017 and December 31, 2016.

Debt Obligations

Debt Obligations	9 Months Ended
	Sep. 30, 2017
Debt Disclosure [Abstract]
Debt Obligations	(13) Debt Obligations Our outstanding debt consists of the following (in thousands): September 30, 2017 December 31, 2016 Revolving credit facility $ 709,652 $ 888,250 8.50% Senior unsecured notes, due 2021 300,000 300,000 3.77% Senior secured notes, due 2031 (non-recourse) 58,649 60,000 Other debt (2) 116 3,762 Total debt obligations 1,068,417 1,252,012 Unamortized debt issuance costs (1) (9,338 ) (11,036 ) Total debt 1,059,079 1,240,976 Less: Current portion, including unamortized debt issuance costs (1,234 ) (5,438 ) Long term debt $ 1,057,845 $ 1,235,538 ___________________________ (1) Unamortized debt issuance costs related to the revolving credit facility are included in our unaudited condensed consolidated balance sheets in Other assets, net. (2) Other debt includes capital lease and miscellaneous long-term obligations, which are reported in Current portion of debt and Other liabilities line items on our unaudited condensed consolidated balance sheets. Credit Facilities Revolving Credit Facility On March 8, 2017, we entered into the Second Amended and Restated Credit Agreement with Bank of America N.A., as Administrative Agent, Collateral Agent and L/C Issuer, Wells Fargo Bank, National Association, as Syndication Agent, and other lenders (the “Credit Agreement”) which increased our borrowing capacity from $750.0 million to $900.0 million and provided for an accordion feature that will permit, subject to customary conditions, the borrowing capacity under the facility to be increased to a maximum of $1.1 billion . 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 (i) the Federal Funds Rate, plus 0.50% , (ii) 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 (iii) 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, which matures on September 5, 2019. The Credit Agreement contains certain financial covenants that are applicable as of the end of any fiscal quarter, including a consolidated total leverage ratio which requires our indebtedness not to exceed 5.00 times adjusted consolidated EBITDA (except for the fiscal quarters ended March 31, 2017, and the subsequent two quarters, at which time the covenant is increased to 5.50 times adjusted consolidated EBITDA), a consolidated secured leverage ratio which requires our secured indebtedness not to exceed 3.50 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 letters of credit outstanding as of September 30, 2017 and December 31, 2016 were $33.1 million and $7.4 million , respectively. As of September 30, 2017 , our consolidated total leverage ratio was 4.68 and our interest coverage ratio was 4.41 , which were both in compliance with the related requirements of our Credit Agreement. Our ability to maintain compliance with the 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. The carrying value of amounts outstanding under our Credit Agreement approximates the related fair value, as interest charges vary with market rates conditions. JPE Revolver JPE had a $275.0 million revolving loan, which included a sub-limit of up to $100.0 million for letters of credit with Bank of America, N.A. (the “JPE Revolver”). The JPE Revolver was scheduled to mature on February 12, 2019, but on March 8, 2017, in connection with the closing of the JPE acquisition, the $199.5 million outstanding balance of the JPE Revolver was paid off in full and terminated. For the nine months ended September 30, 2017 and 2016 , the weighted average interest rate on borrowings under our Credit Agreement was approximately 4.85% and 2.82% , respectively. 8.50% Senior Unsecured Notes On December 28, 2016, we and American Midstream Finance Corporation, our wholly-owned subsidiary (the “Issuers”), completed the issuance and sale of $300 million in aggregate principal amount of senior notes due 2021 (the “ 8.50% Senior Notes”). The 8.50% Senior Notes are jointly and severally guaranteed by certain of our existing direct and indirect wholly owned subsidiaries that guarantee our Credit Agreement. The 8.50% Senior Notes rank equal in right of payment with all existing and future senior indebtedness of the Issuers, and senior in right of payment to any future subordinated indebtedness of the Issuers. The 8.50% Senior Notes were issued at par and provided approximately $294.0 million in proceeds, after deducting the initial purchasers' discount of $6.0 million . This amount was deposited into escrow pending completion of the JPE Acquisition and was included in Restricted cash-long term on our consolidated balance sheet as of December 31, 2016. The 8.50% Senior Notes will mature on December 15, 2021 with interest payable in cash semi-annually in arrears on June 15 and December 15, commencing June 15, 2017. As of September 30, 2017 , the fair value of the 8.50% Senior Notes was $310.2 million . This estimate was based on similar private placement transactions along with changes in market interest rates which represent a Level 2 measurement. 3.77% Senior Secured Notes On September 30, 2016, Midla Financing, LLC (“Midla Financing”), American Midstream (Midla) LLC (“Midla”), and Mid Louisiana Gas Transmission LLC (“MLGT and together with Midla, the “Note Guarantors”) entered into a Note Purchase and Guaranty Agreement (the “Note Purchase Agreement”) with certain institutional investors (the “Purchasers”) whereby Midla Financing issued $60.0 million in aggregate principal amount of 3.77% Senior Notes (non-recourse) due June 30, 2031. Midla Financing must maintain a debt service reserve account containing six months of principal and interest payments, and Midla Financing and the Note Guarantors (including any entities that become guarantors under the terms of the Note Purchase Agreement) are restricted from making distributions (a) until June 30, 2017, (b) unless the debt service coverage ratio is not less than, and is not projected for the following 12 calendar months to be less than, 1.20 :1.00, and (c) unless certain other requirements are met. Net proceeds from the 3.77% Senior Notes are restricted and are used (1) to fund project costs incurred in connection with (a) the construction of the Midla-Natchez Line (b) the retirement of Midla’s existing 1920’s vintage pipeline (c) the move of our Baton Rouge operations to the MLGT system (d) the reconfiguration of the DeSiard compression system and all related ancillary facilities, (2) to pay transaction fees and expenses in connection with the issuance of the 3.77% Senior Notes, and (3) for other general corporate purposes of Midla Financing. As of September 30, 2017 , the fair value of the 3.77% Senior Notes was $55.4 million . This estimate was based on similar private placement transactions along with changes in market interest rates which represent a Level 2 measurement.

Convertible Preferred Units (No

Convertible Preferred Units (Notes)	9 Months Ended
	Sep. 30, 2017
Partners' Capital [Abstract]
Convertible Preferred Units	(14) Convertible Preferred Units Our convertible preferred units consist of the following (in thousands): Series A Series C Series D Total Units $ Units $ Units $ $ December 31, 2016 10,107 $ 181,386 8,792 $ 118,229 2,333 $ 34,475 $ 334,090 Paid in kind unit distributions 429 6,645 — 2,844 — — 9,489 September 30, 2017 10,536 $ 188,031 8,792 $ 121,073 2,333 $ 34,475 $ 343,579 Affiliates of our General Partner hold and participate in quarterly distributions on our convertible preferred units, with such distributions being made in cash, paid-in-kind units or a combination thereof, at the election of the Board of Directors of our General Partner. The convertible preferred unitholders have the right to receive cumulative distributions in the same priority and prior to any other distributions made in respect of any other partnership interests. To the extent that any portion of a quarterly distribution on our convertible preferred units to be paid in cash exceeds the amount of cash available for such distribution, the amount of cash available will be paid to our convertible preferred unitholders on a pro rata basis while the difference between the distribution and the available cash will become arrearages and accrue interest until paid. Series A-1 Convertible Preferred Units On April 15, 2013, we, our General Partner and AIM Midstream Holdings entered into agreements with HPIP, pursuant to which HPIP acquired 90% of our General Partner and all of our subordinated units from AIM Midstream Holdings and contributed the High Point System and $15.0 million in cash to us in exchange for 5,142,857 of our Series A-1 Units. The Series A-1 Units receive distributions prior to distributions to our common unitholders. The distributions on the Series A-1 Units are equal to the greater of $0.4125 per unit or the declared distribution to common unitholders. The Series A-1 Units may be converted into common units, subject to customary anti-dilutive adjustments, at the option of the unitholders on or any time after January 1, 2014. As of September 30, 2017 , the conversion price is $15.24 and the conversion ratio is 1 to 1.1483 . Series A-2 Convertible Preferred Units On March 30, 2015 and June 30, 2015, we entered into two Series A-2 Convertible Preferred Unit Purchase Agreements with Magnolia Infrastructure Partners ("Magnolia") an affiliate of HPIP pursuant to which we issued, in separate private placements, newly-designated Series A-2 Units (the “Series A-2 Units”) representing limited partnership interests in the Partnership. As a result, the Partnership issued a total of 2,571,430 Series A-2 Units for approximately $45.0 million in aggregate proceeds during the year ended December 31, 2015. The Series A-2 Units will participate in distributions of the Partnership along with common units in a manner identical to the existing Series A-1 Units (together with the Series A-2 Units, the "Series A Units"), with such distributions being made in cash or with paid-in-kind Series A Units at the election of the Board of Directors of our General Partner. On July 27, 2015, we amended our Partnership Agreement to grant us the right (the “Call Right”) to require the holders of the Series A-2 Units to sell, assign and transfer all or a portion of the then outstanding Series A-2 Units to us for a purchase price of $17.50 per Series A-2 Unit (subject to appropriate adjustment for any equity distribution, subdivision or combination of equity interests in the Partnership). We may exercise the Call Right at any time, in connection with our or our affiliate’s acquisition of assets or equity from ArcLight Energy Partners Fund V, L.P., or one of its affiliates, for a purchase price in excess of $100 million . We may not exercise the Call Right with respect to any Series A-2 Units that a holder has elected to convert into common units on or prior to the date we have provided notice of our intent to exercise the Call Right, and we may also not exercise the Call Right if doing so would result in a default under any of our or our affiliates’ financing agreements or obligations. As of September 30, 2017 , the conversion price is $15.24 and the conversion ratio is 1 to 1.1483 . As conversion is at the option of the holder and redemption is contingent upon a future event which is outside the control of the Partnership, the Series A-1 and A-2 Units have been classified as mezzanine equity in the condensed consolidated balance sheets. Series C Convertible Preferred Units On April 25, 2016, we issued 8,571,429 Series C Units to an ArcLight affiliate in connection with the purchase of membership interests in certain midstream entities. 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 the sum of $14.00 plus all accrued and accumulated but unpaid distributions, divided by the conversion price. The sale of the Series C Units was exempt from registration under Securities Act pursuant to Rule 4(a)(2) under the Securities Act. In the event that we issue, sell or grant 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 price 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. As of September 30, 2017 , the conversion price is $13.40 and the conversion ratio is 1 to 1.0448 . In connection with the issuance of the Series C Units, we issued the holders a warrant to purchase up to 800,000 common units at an exercise price of $7.25 per common unit (the "Series C Warrant"). The Series C Warrant is subject to standard anti-dilution adjustments and is exercisable for a period of seven years. The fair value of the Series C 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 . As conversion is at the option of the holder and redemption is contingent upon a future event which is outside the control of the Partnership, the Series C Units have been classified as mezzanine equity in the condensed consolidated balance sheets. Series D Convertible Preferred Units On October 31, 2016, we issued 2,333,333 shares of our newly-designated Series D Units to an ArcLight affiliate at a price of $15.00 per unit, less a 1.5% closing fee, in connection with the Delta House transaction during the third quarter 2016. The related agreement provides that if any of the Series D Units remain outstanding on June 30, 2017 (the “ Series D Determination Date”), we will issue the holder of the Series D Units a warrant (the “Series D Warrant”) to purchase 700,000 common units representing limited partnership interests with an exercise price of $22.00 per common unit. The fair value of the conditional Series D Warrant at the time of issuance was immaterial. On July 14, 2017, the Partnership entered into an amendment to the related agreement and Amendment No. 5 to the Partnership Agreement, pursuant to which the Series D Warrant Determination Date was extended to August 31, 2017. The Series D Units are entitled to quarterly distributions payable in arrears equal to the greater of $0.4125 and the cash distribution that the Series D Units would have received if they had been converted to common units immediately prior to the beginning of the quarter. The Series D 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 D Units. The Series D Units are convertible in whole or in part into common units at the election of the holder of the Series D Unit at any time after October 2, 2017. As of the date of issuance, the conversion rate for each Series D Unit was one -to-one (the “Conversion Rate”). As of September 30, 2017 , the conversion price is $14.83 and the conversion ratio is 1 to 1.0035 . As conversion is at the option of the holder and redemption is contingent upon a future event which is outside the control of the Partnership, the Series D Units have been classified as mezzanine equity in the condensed consolidated balance sheets. On October 2, 2017, AMID exercised its call right to repurchase all of the 2,333,333 outstanding Series D Units. As a result, no Series D Units are outstanding currently. See Note 22 - Subsequent Events . Third Amendment to Partnership Agreement On March 8, 2017, the Partnership executed Amendment No. 3 to our Fifth Amended and Restated Partnership Agreement (as amended, the “Partnership Agreement”), which amends the distribution payment terms of the Partnership’s outstanding Series A Preferred Units to provide for the payment of a number of Series A payment-in-kind (“PIK”) preferred units for the quarter (the “Series A Preferred Quarterly Distribution”) in which the JPE Acquisition is consummated (which is the quarter ended March 31, 2017) and each quarter thereafter equal to the quotient of (i) the greater of (a) $0.4125 and (b) the "Series A Distribution Amount," as such term is defined in the Partnership Agreement, divided by (ii) the Series A Adjusted Issue Price, as such term is defined in the Partnership Agreement. However, in our General Partner’s discretion, which determination shall be made prior to the record date for the relevant quarter, the Series A Preferred Quarterly Distribution may be paid as a combination (x) an amount in cash up to the greater of (1) $0.4125 and (2) the Series A Distribution Amount, and (y) a number of Series A Preferred Units equal to the quotient of (a) the remainder of (i) the greater of (I) $0.4125 and (II) the Series A Distribution Amount less (ii) the amount of cash paid pursuant to clause (x), divided by (b) the Series A Adjusted Issue Price. This calculation results in a reduced Series A Preferred Quarterly Distribution, which was previously calculated under the Partnership Agreement using $0.50 in place of $0.4125 in the preceding calculations.

Partners Capital

Partners Capital	9 Months Ended
	Sep. 30, 2017
Equity [Abstract]
Partners’ Capital and Convertible Preferred Units	(15) Partners’ Capital Our capital accounts are comprised of approximately 1.3% notional General Partner interests and 98.7% limited partner interests as of September 30, 2017 . 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. Outstanding Units The following table presents unit activity (in thousands): General Limited Partner Interest Balances at December 31, 2016 680 51,351 LTIP vesting — 460 Issuance of GP units 273 — Issuance of common units (1) — 929 Balances at September 30, 2017 953 52,740 ____________________________________ (1) Including common units issued in connection with the Panther acquisition. See Note 3 - Acquisitions . General Partner Units In order to maintain the ownership percentage, we received proceeds of $3.9 million from our General Partner as consideration for the issuance of 272,811 additional notional General Partner units for the nine months ended September 30, 2017 . For the nine months ended September 30, 2016 , we received proceeds of $1.9 million for the issuance of 135,813 additional notional General Partner units. Distributions We made the following distributions (in thousands): Three months ended September 30, Nine months ended September 30, 2017 2016 2017 2016 Series A Units Cash Paid $ 2,145 $ 2,449 $ 6,790 $ 2,449 Accrued 4,105 4,806 4,105 4,806 Paid-in-kind units 1,924 2,152 6,838 6,623 Series C Units Cash Paid 3,627 1,302 10,880 1,302 Accrued 4,150 3,611 4,150 3,611 Paid-in-kind units — 948 — 948 Series D Units Cash Paid 963 — 2,888 — Accrued — — — — Limited Partner Units Cash Paid 21,345 24,874 67,648 76,656 General Partner Units Cash Paid 277 174 645 2,375 Summary Cash Paid 28,357 28,799 88,851 82,782 Accrued 8,255 8,417 8,255 8,417 Paid-in-kind units 1,924 3,100 6,838 7,571 The fair value of the paid-in-kind distributions was determined 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 $0.88 per unit to $3.39 per unit using a Black-Scholes model, iii) assumed discount rates ranging from 5.8% to 10.0% and iv) assumed growth rates of 1.0% .

Net Loss per Limited Partner Un

Net Loss per Limited Partner Unit	9 Months Ended
	Sep. 30, 2017
Earnings Per Share [Abstract]
Net Loss per Limited Partner Unit	(16) Net Income (loss) per Limited Partner Unit Net income (loss) is allocated to the General Partner and the limited partners in accordance with their respective ownership percentages, after giving effect to distributions on our convertible preferred units and General Partner units, including incentive distribution rights. Unvested unit-based compensation awards that contain non-forfeitable rights to distributions (whether paid or unpaid) are classified as participating securities and are included in our computation of basic and diluted net 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 loss by the weighted average number of outstanding limited partner units during the period. The calculation of basic and diluted limited partners' net income (loss) per common unit is summarized below (in thousands, except per unit amounts): Three months ended September 30, Nine months ended September 30, 2017 2016 2017 2016 Net income (loss) from continuing operations $ 11,806 $ (5,488 ) $ (42,266 ) $ (35,414 ) Less: Net income attributable to noncontrolling interests 621 1,241 3,386 2,192 Net income (loss) from continuing operations attributable to the Partnership 11,185 (6,729 ) (45,652 ) (37,606 ) Less: Distributions on Series A Units 4,105 4,806 12,472 13,879 Distributions on Series C Units 4,150 3,611 11,403 5,860 Distributions on Series D Units — — 1,925 — General partner's distribution 287 174 763 2,375 General partner's share in undistributed loss (210 ) (375 ) (1,729 ) (1,334 ) Net income (loss) from continuing operations attributable to Limited Partners 2,853 (14,945 ) (70,486 ) (58,386 ) Net income (loss) from discontinued operations attributable to Limited Partners 44,696 (2,310 ) 42,185 7,532 Net income (loss) attributable to Limited Partners $ 47,549 $ (17,255 ) $ (28,301 ) $ (50,854 ) Weighted average number of common units used in computation of Limited Partners' net loss per common unit - basic and diluted 52,021 51,310 52,021 51,310 Limited Partners' net income (loss) from continuing operations per unit $ 0.05 $ (0.29 ) $ (1.35 ) $ (1.14 ) Limited Partners' net income (loss) from discontinued operations per unit 0.86 (0.05 ) 0.81 0.15 Limited Partners' net income (loss) per common unit (1) $ 0.91 $ (0.34 ) $ (0.54 ) $ (0.99 ) _____________________________________ (1) Potential common unit equivalents are antidilutive for all periods presented and, as a result, have been excluded from the determination of diluted limited partners' net loss per common unit.

Long-Term Incentive Plan

Long-Term Incentive Plan	9 Months Ended
	Sep. 30, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Long-Term Incentive Plan	(17) 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, among other things, 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”). On March 9, 2017, an additional 312,716 common units were registered to be issued pursuant to the American Midstream Partners, LP Amended and Restated 2014 Long-Term Incentive Plan, which were assumed by the Partnership, in relation to the converted JPE phantom units as part of the merger with JP Energy LP. 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 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, phantom units typically vest over 3 - 4 years 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 contain DERs based on the extent to which our Series A Unitholders receive distributions in cash. These units will vest 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 nine months ended September 30, 2017 : Units Weighted-Average Grant Date Fair Value Per Unit Outstanding units at December 31, 2016 1,558,835 $ 6.98 Granted 2,000 11.20 Forfeited (18,919 ) 13.49 Vested (570,038 ) 11.13 Outstanding units at September 30, 2017 971,878 $ 4.43 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 expenses related to these awards were $ 0.8 million and $1.8 million for the three months ended September 30, 2017 and 2016, respectively, and were $6.1 million and $4.3 million for the nine months ended September 30, 2017 and 2016 , respectively, and are included in Corporate expenses and Direct operating expenses in our unaudited condensed consolidated statements of operations and Equity compensation expense in our unaudited condensed consolidated statements of changes in partners’ capital and noncontrolling interests. The total fair value of units at the time of vesting was $9.4 million and $1.8 million for the nine months ended September 30, 2017 and 2016 , respectively.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2017
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	(18) 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, results of operations or cash flows. Environmental matters We are subject to federal and state laws and regulations relating to the protection of the environment. Environmental risk is inherent to our 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, FERC approved the stipulation and agreement (the “Midla Agreement”) relating to the October 8, 2014 regulatory matter allowing Midla to retire the existing 1920’s pipeline and replace it with 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, we filed with FERC for authorization to construct the Midla-Natchez pipeline, which was approved on December 17, 2015. Construction commenced in the second quarter of 2016, and services commenced on March 31, 2017. Under the Midla Agreement, Midla executed long-term agreements seeking to recover its investment in the Midla-Natchez Line. Acquisition related costs As part of the JPE Acquisition, management of JPE communicated to its employees a severance plan. The plan includes termination benefits in the form of severance and accelerated vesting of phantom units for employees who render service through their respective termination date. The remaining liability associated with these termination benefits was immaterial as of September 30, 2017.

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2017
Related Party Transactions [Abstract]
Related Party Transactions	(19) Related Party Transactions To the extent applicable, our discussion below includes the nature of our relationship and activities that we had with our Related Parties, as defined and required by ASC 850 - Related Party Disclosures, in the three and nine months ended September 30, 2017 and comparative periods. Balances associated with our investments in unconsolidated affiliates are disclosed in Note 10 - Investments in unconsolidated affiliates. Blackwater Midstream Holdings, LLC In December 2013, we acquired Blackwater Midstream Holdings, LLC (“Blackwater”) from an affiliate of ArcLight. The acquisition agreement included a provision whereby an ArcLight affiliate would be entitled to an additional $5.0 million of merger consideration based on Blackwater meeting certain operating targets. During the third quarter of 2016, we determined that it was probable the operating targets would be met in 2017 and recorded a $5.0 million accrued distribution to the ArcLight affiliate which is included in Accrued expense and other current liabilities in the accompanying unaudited condensed consolidated balance sheets. General Partner Employees of our General Partner are assigned to work for us or other affiliates of our General Partner. Where directly attributable, all compensation and related expenses for these employees are charged directly by our General Partner to our wholly-owned subsidiary, American Midstream, LLC, which, in turn, charges the appropriate subsidiary or affiliate. Our General Partner does not record any profit or margin on the expenses charged to us. In connection with the JPE Acquisition closing during the first quarter of 2017, our General Partner agreed to provide quarterly financial support up to a maximum of $25.0 million . The financial support will continue for eight ( 8 ) consecutive quarters following the closing of the acquisition, or earlier, until $25.0 million in support has been provided. As of September 30, 2017, we have utilized the full $25.0 million of the financial support mentioned above. Separate from the financial support described above, our General Partner also agreed to absorb $9.6 million corporate overhead expenses, which were incurred by us in the first quarter of 2017, and subsequently paid the amount in the second quarter of 2017. These two cash amounts, and the $3.9 million received related to the General Partner’s ownership percentage, totaled $38.3 million which was presented as part of the contribution line item on our unaudited condensed consolidated statements of cash flows. As of September 30, 2017 and December 31, 3016, we had $4.7 million and $3.9 million of account payables, 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. Republic Midstream, LLC Republic Midstream, LLC (“Republic”), is an entity owned by ArcLight in which we charge a monthly fee of approximately $0.1 million . The monthly fee reduced the Corporate expenses in the condensed consolidated statements of operations by $0.4 million and $1.0 million for three and nine months ended September 30, 2017, respectively, and $0.2 million and $0.6 million for the three and nine months ended September 30, 2016, respectively. As of September 30, 2017, we had a receivable balance due from Republic of $1.5 million , which is included in the account Receivables from related parties, which is part of Other current assets in the condensed consolidated balance sheets. Transactions with our unconsolidated affiliates Destin and Okeanos On November 1, 2016, we became operator of the Destin and Okeanos pipelines and entered into operating and administrative management agreements under which the affiliates pay a monthly fee for general and administrative services provided by us. In addition, the affiliates reimburse us for certain transition related expenses. For the nine months ended September 30, 2017 , we recognized $1.9 million of management fee income. As of September 30, 2017 and December 31, 2016, we had an outstanding accounts receivable balance of $1.0 million and $2.2 million , respectively, which is recorded in Receivables from related parties and is part of Other current assets in the unaudited condensed consolidated balance sheets. AmPan AmPan was a 60% -owned subsidiary of ours which was consolidated for financial reporting purposes. Panther was the 40% non-controlling interest owner of AmPan. Pursuant to a related party agreement which began in the second quarter of 2016, POGS provided management services to AmPan in exchange for related fees, which in 2016 totaled $0.8 million of Direct operating expenses and $0.4 million of Corporate expenses in the unaudited condensed consolidated statements of operations. During January 1, 2017 to August 7, 2017, such management services totaled approximately $1.5 million of Direct operating expenses and $0.3 million of Corporate expenses in the unaudited condensed consolidated statements of operations. Effective August 8, 2017, AmPan and POGS became our wholly-owned subsidiaries. See Note 3 - Acquisitions . JP Energy Development JP Energy Development (“JP Development”), an affiliate owned by Arclight, had a pipeline transportation business that provided crude oil pipeline transportation services to JPE’s discontinued Mid-Continent Business. As a result of utilizing JP Development’s pipeline transportation services, JPE incurred pipeline tariff fees of $0.4 million for the six months ended June 30, 2016, which have been included in net loss from discontinued operations in the condensed consolidated statements of operations. As of December 31, 2015, we had a net receivable from JP Development of $7.9 million , primarily as the result of the prepayments made in 2014 for the crude oil pipeline transportation services to be provided by JP Development. We recovered these amounts in full on February 1, 2016. On February 1, 2016, JPE sold certain trucking and marketing assets in the Mid-Continent area to JP Development in connection with JP Development’s sale of its GSPP pipeline assets to a third party. During the year ended December 31, 2016, JPE’s general partner agreed to absorb corporate overhead expenses incurred by us and not pass such expense through to us. We record non-cash contributions for these expenses in the quarters subsequent to when they were incurred, which was $0.0 million and $4.0 million for the three and nine months ended September 30, 2017, respectively, and $3.5 million and $7.5 million for the three and nine months ended September 30, 2016, respectively. JPE’s general partner agreed to absorb $0.0 million and $5.0 million of such corporate overhead expenses in the three and nine months ended September 30, 2016, respectively. Purchases and sales of natural gas and crude oil with a related party We enter into separate purchases and sales of natural gas and crude oil with a company whose chief financial officer is the brother of one of our executive officers. During the three months ended September 30, 2017 and 2016 , we recognized revenue of $3.7 million and $1.1 million , respectively, and had purchases not related to receivables totaling $1.1 million , and $1.2 million , respectively. During the nine months ended September 30, 2017 and 2016 , we recognized revenue of $6.2 million and $2.7 million , respectively, and had purchases not related to receivables totaling $3.7 million and $3.0 million , respectively. Capstone Ventures, LLC Capstone Ventures, LLC (“Capstone”) is a marketing company where one of the Partnership’s employees is a partial, non-participating owner. During the three months ended September 30, 2017 and 2016 , we recognized revenue of $0.2 million in both periods. During the nine months ended September 30, 2017 and 2016 , we recognized revenue of $0.7 million and $0.5 million , respectively. McCown Enterprises, LLC McCown Enterprises, LLC (“HCLM”) is a marketing company where one of the Partnership’s employee has 50% ownership. During the nine months ended September 30, 2017 and 2016 , we recognized revenue from HCLM of $0.3 million and $0.2 million , respectively.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information (Notes)	9 Months Ended
	Sep. 30, 2017
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	(20) Supplemental Cash Flow Information Supplemental cash flows and non-cash transactions consist of the following (in thousands): Nine months ended September 30, 2017 2016 Supplemental non-cash information Investing Increase (decrease) in accrued property, plant and equipment purchases $ (15,112 ) $ 4,597 Financing Issuance of common units for the Panther acquisition 12,532 — Contributions from an affiliate holding limited partner interests 4,000 7,500 Issuance of Series C Units and Warrant in connection with the Emerald Transactions — 120,000 Accrued distributions on convertible preferred units 8,255 8,417 Paid-in-kind distributions on convertible preferred units 6,838 7,571 Cancellation of escrow units — 6,817 Accrued distribution from unconsolidated affiliates — 5,000

Reportable Segments

Reportable Segments	9 Months Ended
	Sep. 30, 2017
Segment Reporting [Abstract]
Reportable Segments	(21) Reportable Segments Since the first quarter of 2017, as a result of the acquisition of JPE described in Note 1 - Organization, Basis of Presentation and Summary of Significant Accounting Policies , we realigned the composition of our reportable segments. We restated the items of segment information as reported for the three and nine months ended September 30, 2016 to reflect this new segment adjustment. On September 1, 2017, we sold the Propane Business, as described in Note 4 - Discontinued Operations . Prior to the sale, during July 2017, we moved the trucking business from the Propane Marketing Services segment to the Liquid Pipelines and Services segment. The prior periods were adjusted to reflect that change. With the disposition of the Propane Business, we eliminated the Propane Marketing Services segment. We have classified the results of our Propane Marketing Services segment, including the gain on sale, as discontinued operations in our condensed consolidated statements of operations for all periods presented. Our operations are located in the United States and are organized into five reportable segments: 1) Gas Gathering and Processing Services, 2) Liquid Pipelines and Services, 3) Natural Gas Transportation Services, 4) Offshore Pipelines and Services and 5) Terminalling Services. • Gas Gathering and Processing Services . Our Gas Gathering and Processing Services segment provides “wellhead-to-market” services to producers of natural gas and natural gas liquids, which include transporting raw natural gas 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 and NGLs to various markets and pipeline systems. • Liquid Pipelines and Services . Our Liquid Pipelines and Services segment provides transportation, purchase and sales of crude oil from various receipt points including lease automatic customer transfer (“LACT”) facilities and deliveries to various markets. • Natural Gas Transportation Services . Our Natural Gas Transportation Services segment transports and delivers natural gas from producing wells, receipt points, or pipeline interconnects for shippers and other customers, which include local distribution companies (“LDCs”), utilities and industrial, commercial and power generation customers. • Offshore Pipelines and Services . Our Offshore Pipelines and Services segment gathers and transports natural gas and crude oil from various receipt points to other pipeline interconnects, onshore facilities and other delivery points. • Terminalling Services . Our Terminalling Services segment provides above-ground leasable storage operations at our marine terminals that support various commercial customers, including commodity brokers, refiners and chemical manufacturers to store a range of products and also includes crude oil storage in Cushing, Oklahoma and refined products terminals in Texas and Arkansas. These segments are monitored separately by our chief operating decision maker (“CODM”) for performance and are consistent with our internal financial reporting. The CODM periodically reviews segment gross margin information for each segment to make business decisions. These segments have been identified based on the differing products and services, regulatory environment and the expertise required for these operations. We define total segment gross margin as the sum of the segment gross margins for our Gas Gathering and Processing Services, Liquid Pipelines and Services, Natural Gas Transportation Services, Offshore Pipelines and Services and Terminalling Services. We define segment gross margin in our Gas Gathering and Processing Services segment as total revenue plus unconsolidated affiliate earnings less unrealized gains or plus unrealized losses on commodity derivatives, construction and operating management agreement income and the cost of natural gas, crude oil and NGLs and condensate purchased. We define segment gross margin in our Liquid Pipelines and Services segment as total revenue plus unconsolidated affiliate earnings less unrealized gains or plus unrealized losses on commodity derivatives and the cost of crude oil purchased in connection with fixed-margin arrangements. Substantially all of our gross margin in this segment is fee-based or fixed-margin, with little to no direct commodity price risk. We define segment gross margin in our Natural Gas Transportation Services segment as total revenue plus unconsolidated affiliate earnings less the cost of natural gas purchased in connection with fixed-margin arrangements. Substantially all of our gross margin in this segment is fee-based or fixed-margin, with little to no direct commodity price risk. We define segment gross margin in our Offshore Pipelines and Services segment as total revenue plus unconsolidated affiliate earnings less the cost of natural gas purchased in connection with fixed-margin arrangements. Substantially all of our gross margin in this segment is fee-based or fixed-margin, with little to no direct commodity price risk. We define segment gross margin in our Terminalling Services segment as total revenue less direct operating expense which includes direct labor, general materials and supplies and direct overhead. A reconciliation from Total segment gross margin to Net income (loss) attributable to the Partnership for the periods presented is below (in thousands): Three months ended September 30, Nine months ended September 30, 2017 2016 2017 2016 Reconciliation of Segment Gross Margin to Net income (loss) attributable to the Partnership: Gas Gathering and Processing Services segment gross margin $ 12,761 $ 12,627 $ 36,663 $ 37,586 Liquid Pipelines and Services segment gross margin 7,808 7,600 21,209 23,829 Natural Gas Transportation Services segment gross margin 5,356 3,709 17,106 13,115 Offshore Pipelines and Services segment gross margin 29,312 24,126 80,738 57,947 Terminalling Services segment gross margin (1) 8,509 10,731 30,429 31,760 Total segment gross margin (non-GAAP) 63,746 58,793 186,145 164,237 Less: Direct operating expenses (1) 17,274 14,695 47,316 45,999 Plus: Gain (loss) on commodity derivatives, net (597 ) 324 (33 ) (1,929 ) Less: Corporate expenses 27,083 22,103 84,570 60,945 Depreciation, amortization and accretion expense 26,781 22,668 78,834 65,937 (Gain) loss on sale of assets, net (4,061 ) 36 (4,064 ) 297 Interest expense 17,759 5,830 51,037 24,723 Other (income) expense (34,085 ) 1 (32,248 ) (245 ) Other (income) expense, net (139 ) (1,129 ) 322 (1,773 ) Income tax expense 731 401 2,611 1,839 (Income) loss from discontinued operations, net of tax (44,696 ) 2,310 (42,185 ) (7,532 ) Net income attributable to noncontrolling interests 621 1,241 3,386 2,192 Net income (loss) $ 55,881 $ (9,039 ) $ (3,467 ) $ (30,074 ) _____________________________________ (1) Direct operating expenses include Gas Gathering and Processing Services segment direct operating expenses of $8.7 million and $7.9 million , Liquid Pipelines and Services segment direct operating expenses of $2.4 million and $2.6 million , Natural Gas Transportation Services segment direct operating expenses of $2.2 million and $1.3 million and Offshore Pipelines and Services segment direct operating expenses of $3.9 million and $2.9 million for the three months ended September 30, 2017 and 2016 , respectively. Direct operating expenses related to our Terminalling Services segment of $3.4 million and $2.9 million for the three months ended September 30, 2017 and 2016 , respectively, are included within the calculation of Terminalling Services segment gross margin. Other direct operating expenses include Gas Gathering and Processing Services segment direct operating expenses of $24.8 million and $25.3 million , Liquid Pipelines and Services segment direct operating expenses of $7.1 million and $8.2 million , Natural Gas Transportation Services segment direct operating expenses of $5.4 million and $4.5 million , and Offshore Pipelines and Services segment direct operating expenses of $10.0 million and $8.0 million for the nine months ended September 30, 2017 and 2016 , respectively. Direct operating expenses related to our Terminalling Services segment of $9.5 million and $7.9 million for the nine months ended September 30, 2017 and 2016 , respectively, are included within the calculation of Terminalling Services segment gross margin. The following tables set forth our segment information for the three and nine months ended September 30, 2017 and 2016 (in thousands): Three months ended September 30, 2017 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 37,287 $ 87,022 $ 11,131 $ 14,360 $ 13,087 $ 162,887 Gain (loss) on commodity derivatives, net (65 ) (532 ) — — — (597 ) Total revenue 37,222 86,490 11,131 14,360 13,087 162,290 Earnings in unconsolidated affiliates — 1,317 — 15,510 — 16,827 Operating expenses: Cost of Sales 24,492 80,510 5,692 558 1,146 112,398 Direct operating expenses 8,655 2,438 2,240 3,940 3,432 20,705 Corporate expenses 27,083 Depreciation, amortization and accretion expense 26,781 Gain on sale of assets, net (4,061 ) Total operating expenses 182,906 Interest expense 17,759 Other income (34,085 ) Income from continuing operations before income taxes 12,537 Income tax expense 731 Income from continuing operations 11,806 Income from discontinued operations, including gain on disposition (Note 4) 44,696 Net income 56,502 Less: Net income attributable to non-controlling interests 621 Net income attributable to the Partnership $ 55,881 Segment gross margin $ 12,761 $ 7,808 $ 5,356 $ 29,312 $ 8,509 Three months ended September 30, 2016 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 31,650 $ 87,898 $ 10,709 $ 14,879 $ 14,443 $ 159,579 Gain (loss) on commodity derivatives, net 149 177 — (2 ) — — 324 Total revenue 31,799 88,075 10,709 14,877 14,443 159,903 Earnings in unconsolidated affiliates (1 ) 650 — 9,819 — 10,468 Operating expenses: Cost of Sales 18,477 80,372 6,994 570 836 107,249 Direct operating expenses 7,856 2,617 1,324 2,898 2,876 17,571 Corporate expenses 22,103 Depreciation, amortization and accretion expense 22,668 Loss on sale of assets, net 36 Total operating expenses 169,627 Interest expense 5,830 Other expense 1 Loss from continuing operations before income taxes (5,087 ) Income tax expense 401 Loss from continuing operations (5,488 ) Loss from discontinued operations (2,310 ) Net loss (7,798 ) Less: Net income attributable to non-controlling interests 1,241 Net loss attributable to the Partnership $ (9,039 ) Segment gross margin $ 12,627 $ 7,600 $ 3,709 $ 24,126 $ 10,731 Nine months ended September 30, 2017 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 111,001 $ 253,590 $ 34,966 $ 41,330 $ 47,544 $ 488,431 Gain (loss) on commodity derivatives, net (170 ) 137 — — — (33 ) Total revenue 110,831 253,727 34,966 41,330 47,544 488,398 Earnings in unconsolidated affiliates — 3,886 — 45,895 — 49,781 Operating expenses: Cost of Sales 74,261 236,896 17,630 6,487 7,612 342,886 Direct operating expenses 24,766 7,137 5,403 10,010 9,503 56,819 Corporate expenses 84,570 Depreciation, amortization and accretion expense 78,834 Gain on sale of assets, net (4,064 ) Total operating expenses 559,045 Interest expense 51,037 Other income (32,248 ) Loss from continuing operations before income taxes (39,655 ) Income tax expense 2,611 Loss from continuing operations (42,266 ) Income from discontinued operations, including gain on disposition (Note 4) 42,185 Net loss (81 ) Less: Net income attributable to non-controlling interests 3,386 Net loss attributable to the Partnership $ (3,467 ) Segment gross margin $ 36,663 $ 21,209 $ 17,106 $ 80,738 $ 30,429 Nine months ended September 30, 2016 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 85,655 $ 221,866 $ 28,383 $ 32,526 $ 46,652 $ 415,082 Gain (loss) on commodity derivatives, net (716 ) (772 ) — (5 ) (436 ) (1,929 ) Total revenue 84,939 221,094 28,383 32,521 46,216 413,153 Earnings in unconsolidated affiliates — 1,658 — 27,855 — 29,513 Operating expenses: Cost of Sales 47,344 199,111 15,245 2,429 6,583 270,712 Direct operating expenses 25,344 8,186 4,515 7,954 7,873 53,872 Corporate expenses 60,945 Depreciation, amortization and accretion expense 65,937 Loss on sale of assets, net 297 Total operating expenses 451,763 Interest expense 24,723 Other income (245 ) Loss from continuing operations before income taxes (33,575 ) Income tax expense 1,839 Loss from continuing operations (35,414 ) Income from discontinued operations 7,532 Net loss (27,882 ) Less: Net income attributable to non-controlling interests 2,192 Net loss attributable to the Partnership $ (30,074 ) Segment gross margin $ 37,586 $ 23,829 $ 13,115 $ 57,947 $ 31,760 A reconciliation of total assets by segment to the amounts included in the condensed consolidated balance sheets follows: September 30, December 31, 2017 2016 Segment assets: Gas Gathering and Processing Services $ 416,498 $ 530,889 Liquid Pipelines and Services 443,771 425,389 Offshore Pipelines and Services 544,895 400,193 Natural Gas Transportation Services 172,813 221,604 Terminalling Services 256,922 299,534 Other (1) 188,308 334,953 Discontinued Operations — 136,759 Total Assets $ 2,023,207 $ 2,349,321 _____________________________________ (1) Other assets not allocable to segments consist of corporate leasehold improvements and other miscellaneous assets.

Subsequent Events

Subsequent Events	9 Months Ended
	Sep. 30, 2017
Subsequent Events [Abstract]
Subsequent Events	(22) Subsequent Events Series D Units Redemption On October 2, 2017, pursuant to the terms of the Fifth Amended and Restated Agreement of Limited Partnership, as amended, of the Partnership, we exercised our call right to repurchase all of the 2,333,333 outstanding Series D Convertible Preferred Units representing limited partner interests in the Partnership (“Series D Units”) from Magnolia Infrastructure Holdings, LLC, an affiliate of ArcLight, for approximately $37.0 million in cash, which was funded through our existing revolver. After the closing date of such redemption, which occurred on October 2, 2017, no Series D Units remain outstanding. Distribution On October 26, 2017 , we announced that the Board of Directors of our General Partner declared a quarterly cash distribution of $0.4125 per common unit and preferred unit, Series A and Series C, for the quarter ended September 30, 2017 , or $1.65 per common unit on an annualized basis. The distribution is expected to be paid on November 14, 2017 , to unitholders of record as of the close of business on November 7, 2017 . Acquisition of additional ownership interest in Destin On October 27, 2017, American Midstream Emerald, LLC, a wholly-owned subsidiary of the Partnership, entered into a Purchase and Sale Agreement with Emerald Midstream, LLC, an ArcLight affiliate, to purchase an additional 17.0% equity interest in Destin Pipeline Company, LLC (“Destin”) for total consideration of $30.0 million . With the acquisition, the Partnership will own a 66.67% interest in Destin. The Destin pipeline is a FERC-regulated, 255 -mile natural gas transport system with total capacity of 1.2 Bcf/d. Southcross Energy Partners, L.P. Merger On October 31, 2017, we, our General Partner, our wholly owned subsidiary Cherokee Merger Sub LLC (“Merger Sub”), Southcross Energy Partners, L.P. (“SXE”), and Southcross Energy Partners GP, LLC (“SXE GP”), entered into an Agreement and Plan of Merger (the “SXE Merger Agreement”). Upon the terms and subject to the conditions set forth in the SXE Merger Agreement, SXE will merge with Merger Sub (the “SXE Merger”), with SXE continuing its existence under Delaware law as the surviving entity in the SXE Merger and wholly owned subsidiary of us. The acquisition is valued at approximately $815 million , including the repayment of estimated net debt of $139 million . At the effective time of the SXE Merger (the “Effective Time”), each common unit of SXE (each, an “SXE Common Unit”) issued and outstanding or deemed issued and outstanding as of immediately prior to the Effective Time will be converted into the right to receive 0.160 (the “Exchange Ratio”) of a common unit (each, an “AMID Common Unit”) representing limited partner interests in us (the “Merger Consideration”), except for those SXE Common Units held by affiliates of SXE and SXE GP, which will be cancelled for no consideration. Each SXE Common Unit, Subordinated Unit (as defined in the SXE Merger Agreement) and Class B Convertible Unit (as defined in the SXE Merger Agreement) held by Southcross Holdings LP (“Holdings LP”) or any of its subsidiaries and the SXE Incentive Distribution Rights (as defined in the SXE Merger Agreement) outstanding immediately prior to the Effective Time will be cancelled in connection with the closing of the SXE Merger. In connection with the SXE Merger Agreement, on October 31, 2017, we and our General Partner entered into a Contribution Agreement (the “SXE Contribution Agreement” and, together with the SXE Merger Agreement, the “SXE Transaction Agreements”) with Holdings LP. Upon the terms and subject to the conditions set forth in the SXE Contribution Agreement, Holdings LP will contribute its equity interests in its new wholly owned subsidiary (“SXH Holdings”), which will hold substantially all the current subsidiaries (Southcross Holdings Intermediary LLC, Southcross Holdings Guarantor GP LLC and Southcross Holdings Guarantor LP) and business of Holdings LP, to us and our General Partner in exchange for (i) the number of AMID Common Units with a value equal to $185,697,148 , subject to certain adjustments for cash, indebtedness, working capital and transaction expenses contemplated by the SXE Contribution Agreement, divided by $13.69 per AMID Common Unit, (ii) 4,500,000 AMID Preferred Units (as defined in the SXE Contribution Agreement), (iii) options to purchase 4,500,000 AMID Common Units (the “Options”), and (iv) 3,000 AMID GP Class D Units (as defined in the SXE Contribution Agreement) (the transactions contemplated thereby and the agreements ancillary thereto, the “SXE Contribution”). A portion of the consideration will be deposited into escrow in order to secure certain post-closing obligations of Holdings LP. Concurrently with the closing of the transaction, our agreement of limited partnership will be amended to reflect the issuance of AMID Preferred Units, and the GP LLC Agreement will be amended to reflect the issuance of such AMID GP Class D Units. Acquisition of Trans-Union pipeline On November 6, 2017, we announced the acquisition and closing of 100% of the equity interests in Trans-Union Interstate Pipeline, LP (“Trans-Union”) from affiliates of ArcLight, for a total consideration of approximately $48.0 million . The consideration consisted of approximately $15.5 million cash funded from borrowings under our revolving credit facility and the assumption of $32.5 million of non-recourse debt. Trans-Union owns a 42-mile, 30-inch diameter high-pressure FERC-regulated natural gas interstate pipeline with 546,000 MMbtu/day of maximum capacity. We believe that this acquisition represents a transaction among entities under common control. Accordingly we may have to recast our historical financial statements to reflect the accounts of Trans-Union from the date ArcLight obtained control.

Organization, Basis of Presen32

Organization, Basis of Presentation and Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
JPE Acquisition	JPE Acquisition On March 8, 2017, we completed the acquisition of JP Energy Partners LP (“JPE”), an entity controlled by ArcLight affiliates, in a unit-for-unit merger (“JPE Acquisition”). In connection with the transaction, we issued approximately 20.2 million common units to holders of the JPE common and subordinated units, including 9.8 million common units to ArcLight affiliates. In connection with the completion of the JPE Acquisition, we entered into a supplemental indenture pursuant to which the JPE Entities jointly and severally, fully and unconditionally, guarantee the 8.50% Senior Notes (as defined below). As both we and JPE were controlled by ArcLight affiliates, the acquisition represented a transaction among entities under common control. Although we are the legal acquirer, JPE was considered the acquirer for accounting purposes as ArcLight obtained control of JPE prior to obtaining control of us on April 15, 2013. As a result, we adjusted our historical financial statements to reflect ArcLight’s acquisition cost basis of their investment in us back to April 15, 2013. In addition, the accompanying financial statements and related notes have been retrospectively adjusted to include the historical results of JPE prior to the effective date of the JPE Acquisition. The accompanying financial statements and related notes present the combined financial position, results of operations, cash flows and equity of JPE at historical cost.
Disposition of Propane Business	Disposition of Propane Business On September 1, 2017, we completed the disposition of our Propane Marketing Services business the ("Propane Business") pursuant to the Membership Interest Purchase Agreement dated July 21, 2017, between AMID Merger LP, a wholly owned subsidiary of the Partnership, and SHV Energy N.V. As a result of the disposition of our Propane Business, we classified the results of operations of the Propane Business as discontinued operations. See Note 4 - Discontinued Operations.
Nature of Business	Nature of business We provide critical midstream infrastructure that links producers of natural gas, crude oil, NGLs, condensate and specialty chemicals to numerous intermediate and end-use markets. Through our five reportable segments, (1) gas gathering and processing services, (2) liquid pipelines and services, (3) natural gas transportation services, (4) offshore pipelines and services and (5) terminalling services, we engage 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; storing specialty chemical products and selling refined products. Most of our cash flow is generated from fee-based and fixed-margin arrangements for gathering, processing, transporting and treating natural gas and crude oil, firm capacity reservation charges, interruptible transportation charges, guaranteed firm storage contracts, throughput fees and other optional charges associated with ancillary services. Our primary assets are strategically located in some of the most prolific onshore and offshore producing regions and key demand markets in the United States. Our gathering and processing assets are primarily located in (i) the Permian Basin of West Texas, (ii) the Cotton Valley/Haynesville Shale of East Texas, (iii) the Eagle Ford Shale of South Texas, (iv) the Bakken Shale of North Dakota, and (v) offshore in the Gulf of Mexico. Our natural gas transportation, offshore pipelines and terminal assets are in key demand markets in Alabama, Arkansas, Louisiana, Mississippi and Tennessee and in the Port of New Orleans in Louisiana and the Port of Brunswick in Georgia.
Basis of Presentation	Basis of presentation The financial statements and supplementary data, management’s discussion and analysis of financial condition and results of operations and certain selected financial data in our Form 10-K for the year ended December 31, 2016 (the “Annual Report”), as filed with the U.S. Securities and Exchange Commission (the “SEC”) on March 28, 2017, were recast by the Current Report on Form 8-K, dated September 18, 2017 (“Recast Form 8-K”). There have been no revisions or updates to any other sections of the Annual Report other than the revisions noted above. The unaudited financial information included in this Quarterly Report has been prepared on the same basis as the audited consolidated financial statements included in the Recast Form 8-K, and recast to retrospectively reflect the change in classification of the Propane Business to discontinued operations for all periods presented. The results of operations for the three and nine months ended September 30, 2017 are not necessarily indicative of results expected for the full year. In the opinion of our management, such financial information reflects all adjustments necessary for a fair statement of the financial position and the results of operations for such interim periods in accordance with GAAP. All such adjustments are of a normal recurring nature.
Consolidation	All intercompany items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.
Transactions between Entities under Common Control	Transactions between entities under common control We have entered, and may enter, into transactions with ArcLight affiliates whereby we receive midstream assets or other businesses in exchange for cash or Partnership equity. We account for the net assets acquired at the affiliate's historical cost basis as the transactions are between entities under common control. In certain cases, our historical financial statements were revised to include the results attributable to the assets acquired from the later of June 2011 (the date Arclight affiliates obtained control of JPE) or the date the ArcLight affiliate obtained control of the assets acquired.
Use of Estimates	Use of estimates When preparing 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.
Cash, Cash Equivalents and Restricted Cash	Cash, cash equivalents and restricted cash We consider all highly liquid investments with an original maturity of three months or less at the date of purchase to be cash equivalents. The carrying value of cash and cash equivalents approximates fair value because of the short term to maturity of these investments. From time to time we are required to maintain cash in separate accounts the use of which is restricted by the terms of our debt agreements, asset retirement obligations and contracted arrangements. Such amounts are included in Restricted cash in our unaudited condensed consolidated balance sheets.
Allowance for Doubtful Accounts	Allowance for doubtful accounts We establish provisions for losses on accounts receivable when we determine that we will not collect all or part of an outstanding balance. Collectability is reviewed regularly and an allowance is established or adjusted, as necessary, using the specific identification method, historical collection experience and the age of accounts receivable.
Investment in Unconsolidated Affiliates	Investments in unconsolidated affiliates We hold membership interests in entities that own and operate natural gas pipeline systems and NGL and crude oil pipelines in and around Louisiana, Alabama, Mississippi and the Gulf of Mexico. While we have significant influence over these entities, we do not control them and therefore, they are accounted for using the equity method and are reported in Investment in unconsolidated affiliates in the condensed consolidated balance sheets. We evaluate the recoverability of these investments on a regular basis and recognize impairment write downs if we determine a loss in value represents an other-than-temporary-decline. The unconsolidated affiliates that were determined to be variable interest entities (“VIE”) due to disproportionate economic interests and decision making rights were further evaluated under the VIE method of consolidation. In each case, we lack the power to direct the activities that most significantly impact the unconsolidated affiliate’s economic performance. Therefore, as we do not hold a controlling financial interest in these affiliates, we account for our related investments using the equity method. Additionally, our maximum exposure to loss related to each entity is limited to our equity investment as presented on the condensed consolidated balance sheets as of the balance sheet date. In each case, we are not obligated to absorb losses greater than our proportional ownership percentages. Our right to receive residual returns is not limited to any amount less than the ownership percentages. We also have a joint venture arrangement in which we and our partners share proportional ownership and responsibilities and receive returns in accordance with our ownership percentage.
Revenue Recognition	Revenue recognition We recognize revenue from the sale of commodities (e.g., natural gas, crude oil, NGLs, refined products or condensate) as well as from the provision of gathering, processing, transportation or storage services when all of the following criteria are met: i) persuasive evidence of an exchange arrangement exists, ii) delivery has occurred or services have been rendered, iii) the price is fixed or determinable, and iv) collectability is reasonably assured. We recognize revenue from the sale of commodities and the related cost of product sold on a gross basis for those transactions where we act as the principal and take title to commodities that are purchased for resale. Revenue-related taxes collected from customers and remitted to taxing authorities, principally sales taxes, are presented on a net basis within the unaudited condensed consolidated statements of operations.
Accounting Standards Issued Not Yet Adopted	Accounting Standards Issued Not Yet Adopted In May 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-09, “ Revenue from Contracts with Customers (Topic 606)” , which amends the existing accounting guidance for revenue recognition. The update 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 No. 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. From March 2016 to May 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; ASU No. 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 and ASU No. 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. We are in the process of reviewing our various customer arrangements in order to determine the impact the new accounting guidance for revenue recognition will have on our consolidated financial statements and related disclosures. We also have engaged a third-party consulting firm to assist us with all the three phases of adoption of the new guidance (Impact Assessment, Convert and Implement). We are currently in the Convert phase and revenue streams have been determined. Certain preliminary testing has been performed to validate such streams. We will adopt the new standard on its effective date January 1, 2018 using the modified retrospective method of adoption. In February 2016, the FASB issued ASU No. 2016-02 (Topic 842) " Leases ", which supersedes the lease recognition requirements in ASC Topic 840, "Leases". Under ASU No. 2016-02 lessees are required to recognize assets and liabilities on the balance sheet for most leases and provide enhanced disclosures. Leases will continue to be classified as either finance or operating. ASU No. 2016-02 is effective for annual reporting periods, and interim periods within those years beginning after December 15, 2018. Entities are required to use a modified retrospective approach for leases that exist or are entered into after the beginning of the earliest comparative period in the financial statements, and there are certain optional practical expedients that an entity may elect to apply. Full retrospective application is prohibited and early adoption by public entities is permitted. We are in the process of evaluating the impact of ASU 2016-02 on our consolidated financial statements as we will be required to reflect our various lease obligations and associated asset use rights on our consolidated balance sheets. The adoption may also impact our debt covenant compliance and may require us to modify or replace certain of our existing information systems. We will adopt the guidance on its effective date January 1, 2019. In August 2016, the FASB issued ASU No. 2016-15, “ Statement of Cash Flows (Topic 320): Classification of Cash Receipts and Cash Payments” , which addresses eight specific cash flow issues with the objective of reducing the existing diversity of presentation and classification in the statement of cash flows. ASU No. 2016-15 is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal periods. The retrospective transition method of adoption is required unless it is impracticable. Early adoption is permitted, but only if all aspects are adopted in the same period. We are still evaluating the impact of this update on our consolidated statements of cash flows and the related disclosures. We will adopt the standard upon its effective date January 1, 2018. In November 2016, the FASB issued ASU No. 2016-18, “ Statement of Cash Flows (Topic 230): Restricted Cash” , which aims to improve the disclosure of the change during the period in total cash, cash equivalents and amounts generally described as restricted cash or restricted cash equivalents. Amounts generally described as restricted cash or restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts on the statement of cash flows. The update is effective beginning first quarter of 2018. Early adoption is permitted, but it must occur in the first interim period. Any adjustments required in early adoption of this update should be reflected as of the beginning of the fiscal year that includes the interim period and should be applied using a retrospective transition method to each period. We will adopt the standard on its effective date of January 1, 2018. In January 2017, the FASB issued ASU No. 2017-01 , “Business Combinations (Topic 805): Clarifying the Definition of a Business”. The guidance provides criteria for use in determining when to conclude an integrated “set of assets and activities (as defined in the original guidance) being acquired or disposed in a transaction is not a business. Where the criteria are not met, more stringent screening has been provided to define a set as a business without an output, as more narrowly defined within the guidance. ASU No. 2017-01 is effective for annual periods beginning after December 15, 2017, including interim periods within those periods. The amendments should be applied prospectively on or after the effective date. Early adoption is permitted. We are still in the process of evaluating the guidance and can not determine the impact of this guidance on our consolidated financial statements and related disclosures. We will adopt ASU 2017-01 on its effective date of January 1, 2018. In January 2017, the FASB issued ASU No. 2017-04 , “Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment” , in which the guidance on testing for goodwill was updated by the elimination of Step 2 in the determination on whether goodwill should be considered impaired. The annual and/or interim assessments are still required to be completed. Further, the guidance eliminates the requirement to assess reporting units with zero or negative carrying values, however, the carrying values for all reporting units must be disclosed. ASU No. 2017-04 is effective for annual or any interim goodwill impairment tests beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. We elected to early adopt the guidance in connection with our annual assessment to be performed in October 2017 using the required prospective method. In May 2017, the FASB issued ASU No. 2017-09 , “Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting” , to provide guidance about which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting. Pursuant to this ASU, an entity should account for the effects of a modification unless all the following are met: (1) the fair value (or calculated value or intrinsic value, if such an alternative measurement method is used) of the modified award is the same as the fair value (or calculated value or intrinsic value, if such an alternative measurement method is used) of the original award immediately before the original award is modified (if the modification does not affect any of the inputs to the valuation technique that the entity uses to value the award, the entity is not required to estimate the value immediately before and after the modification); (2) the vesting conditions of the modified award are the same as the vesting conditions of the original award immediately before the original award is modified; and (3) the classification of the modified award as an equity instrument or a liability instrument is the same as the classification of the original award immediately before the original award is modified. ASU No. 2017-09 is effective for annual periods beginning after December 15, 2017, including interim periods within those periods. Early adoption is permitted, including adoption in any interim period. This update should be applied prospectively to an award modified on or after the adoption date. We do not believe that the impact of this update on our consolidated financial statements and related disclosures will be material and will adopt the guidance on its effective date January 1, 2018.

Acquisitions Acquisitions (Tabl

Acquisitions Acquisitions (Tables)	9 Months Ended
	Sep. 30, 2017
Business Combinations [Abstract]
Schedule of Business Acquisitions, by Acquisition	The following table presents the aggregated preliminary allocation of the purchase price based on estimated fair values of Panther’s assets acquired and liabilities assumed (in thousands): Purchase Price Allocation Fair value of acquired noncontrolling interest $ 28,298 Property, plant and equipment 16,870 Intangibles (customer relationships) 9,989 Net working capital, net of cash acquired 2,410 Other 2,975 Asset retirement obligation $ (3,367 ) Total consideration $ 57,175 The following table presents our aggregated allocation of the purchase price based on estimated fair values of assets and liabilities acquired (in thousands): As of September 30, 2017 Purchase Price Allocation Property, plant and equipment: Pipelines and right-of-way $ 13,433 Equipment 18,853 Total property, plant and equipment 32,286 Liability (286 ) Total cash consideration $ 32,000

Discontinued Operations (Tables

Discontinued Operations (Tables)	9 Months Ended
	Sep. 30, 2017
Discontinued Operations and Disposal Groups [Abstract]
Discontinued Operations	The following tables summarize the financial information related to the Propane Business for the periods presented, as required by ASC 420 - Discontinued Operations . Unaudited Condensed Consolidated Balance Sheet of the discontinued operation Propane Business (in thousands) December 31, 2016 Total current assets of discontinued operations $ 22,727 Total noncurrent assets of discontinued operations 114,032 Total assets of discontinued operations $ 136,759 Total current liabilities of discontinued operations $ 14,319 Other long-term liabilities of discontinued operations 172 Total liabilities of discontinued operations $ 14,491 Unaudited Condensed Consolidated Statements of Operations of the discontinued operation Propane Business (in thousands) Three months ended September 30, Nine months ended September 30, 2017 2016 2017 2016 (1) Total revenue $ 20,458 $ 27,756 $ 87,615 $ 103,718 Total operating expenses 22,489 30,158 92,196 96,003 Income (loss) from discontinued operations before taxes (1,834 ) (2,310 ) (4,301 ) 8,069 Income tax benefit (expense) (15 ) — (59 ) 2 Income (loss) from discontinued operations (1,849 ) (2,310 ) (4,360 ) 8,071 Gain from the sale of discontinued operations 46,545 — 46,545 — Partnership’s income (loss) from discontinued operations, including gain on sale. $ 44,696 $ (2,310 ) $ 42,185 $ 8,071 _____________________________________ (1) Amounts for the nine months ended September 30, 2016 do not included the results of certain trucking and marketing assets of JPE in the Mid-Continent area (the “Mid Continent Business”), which were sold in the first quarter of 2016 and are classified as discontinued operations. The total revenue, total operating expenses and loss from discontinued operations related to the Mid Continent Business for the nine months ended September 30, 2016 were $11.5 million , $12.0 million and $0.5 million respectively. Other selected unaudited financial information related to the Propane Business (in thousands) Three months ended September 30, Nine months ended September 30, 2017 2016 2017 2016 Depreciation and amortization $ 2,355 $ 3,850 $ 9,823 $ 12,020 Capital expenditures 722 1,483 3,143 3,451 Other operating and investing non-cash items related to discontinued operations: (Gain) loss on sales of assets, net 118 725 (55 ) 2,064 Unrealized (gain) loss on derivatives contracts, net (526 ) 106 530 (628 )

Inventory (Tables)

Inventory (Tables)	9 Months Ended
	Sep. 30, 2017
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventory consists of the following (in thousands): September 30, 2017 December 31, 2016 Crude oil $ 4,565 $ 1,216 NGLs 232 288 Refined products 674 — Materials, supplies and equipment 499 486 Total inventory $ 5,970 $ 1,990

Other Current Assets (Tables)

Other Current Assets (Tables)	9 Months Ended
	Sep. 30, 2017
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of Other Current Assets	Other current assets consist of the following (in thousands): September 30, 2017 December 31, 2016 Prepaid insurance $ 1,428 $ 9,702 Insurance receivables 3,728 1,624 Due from related parties 5,062 4,833 Other receivables 2,768 2,997 Risk management assets 1,827 469 Other assets 2,331 5,891 Total other current assets $ 17,144 $ 25,516

Risk Management Activities (Tab

Risk Management Activities (Tables)	9 Months Ended
	Sep. 30, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of notional amounts of outstanding derivative positions	The following table summarizes the net notional volumes of our outstanding commodity-related derivatives, excluding those contracts that qualified for the NPNS exception as of September 30, 2017 and December 31, 2016, none of which were designated as hedges for accounting purposes. September 30, 2017 December 31, 2016 Commodity Swaps Volume Maturity Volume Maturity NGLs Fixed Price (gallons) 819,000 January 8, 2018 Crude Oil Fixed Price (barrels) 125,000 October 6, 2017 - December 7, 2017 — — Crude Oil Basis (barrels) — — 180,000 January 25, 2017- March 25, 2017
Fair value associated with commodity derivative instruments	The following table summarizes the fair values of our derivative contracts (before netting adjustments) included in the condensed consolidated balance sheets (in thousands): Asset Derivatives Liability Derivatives Type Balance Sheet Classification September 30, December 31, 2016 September 30, December 31, 2016 Commodity swaps Other current assets $ 267 $ 112 $ — $ — Commodity swaps Accrued expenses and other current liabilities — — (653 ) (1 ) Commodity swaps Other liabilities — — — (1 ) Interest rate swaps Other current assets 1,041 Interest rate swaps Risk management assets (long-term) 7,545 10,628 — — Interest rate swaps Accrued expenses and other current liabilities — — — (252 ) Weather derivatives Other current assets $ 786 $ 429 $ — $ — Total $ 9,639 $ 11,169 $ (653 ) $ (254 ) The following tables present the fair value of our recognized derivative assets and liabilities on a gross basis and amounts offset in the condensed consolidated balance sheets that are subject to enforceable master netting arrangements (in thousands): Gross Risk Management Position Netting Adjustments Net Risk Management Position Balance Sheet Classification September 30, December 31, 2016 September 30, December 31, 2016 September 30, December 31, 2016 Other current assets $ 2,094 $ 541 $ (267 ) $ (72 ) $ 1,827 $ 469 Risk management assets- long term 7,545 10,628 — (1 ) 7,545 10,627 Total assets $ 9,639 $ 11,169 $ (267 ) $ (73 ) $ 9,372 $ 11,096 Accrued expenses and other liabilities $ (653 ) $ (253 ) $ 267 $ 72 $ (386 ) $ (181 ) Other liabilities — (1 ) — 1 — — Total liabilities $ (653 ) $ (254 ) $ 267 $ 73 $ (386 ) $ (181 )
Realized and unrealized gains (losses) with commodity and interest rate derivative instruments	For each of the three and nine months ended September 30, 2017 and 2016 the realized and unrealized gains (losses) associated with our commodity, interest rate and weather derivative instruments were recorded in our unaudited condensed consolidated statements of operations as follows (in thousands): Three months ended September 30, Nine months ended September 30, Statement of Operations Classification Realized Unrealized Realized Unrealized 2017 Gains (losses) on commodity derivatives, net $ (51 ) $ (546 ) $ 465 $ (498 ) Interest expense 51 221 (19 ) (1,790 ) Direct operating expenses (278 ) — (753 ) — Total $ (278 ) $ (325 ) $ (307 ) $ (2,288 ) 2016 Gains (losses) on commodity derivatives, net $ (742 ) $ 1,066 $ (1,432 ) $ (497 ) Interest expense (75 ) 2,109 (106 ) (1,934 ) Direct operating expenses (257 ) — (708 ) — Total $ (1,074 ) $ 3,175 $ (2,246 ) $ (2,431 )

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	9 Months Ended
	Sep. 30, 2017
Property, Plant and Equipment [Abstract]
Property, plant and equipment	Property, plant and equipment, net, consists of the following (in thousands): Useful Life (in years) September 30, December 31, Land Infinite $ 18,440 $ 18,861 Construction in progress N/A 81,133 128,519 Buildings and improvements 4 to 40 13,782 13,762 Transportation equipment 5 to 15 22,743 20,010 Processing and treating plants 8 to 40 141,334 120,977 Pipelines, compressors and right-of-way 3 to 40 958,004 804,815 Storage 3 to 40 146,473 146,408 Equipment 3 to 31 79,567 77,978 Total property, plant and equipment 1,461,476 1,331,330 Accumulated depreciation (320,650 ) (264,722 ) Property, plant and equipment, net $ 1,140,826 $ 1,066,608

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	9 Months Ended
	Sep. 30, 2017
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Goodwill	Goodwill consists of the following (in thousands): September 30, 2017 December 31, 2016 Liquid Pipelines and Services $ 113,671 $ 113,671 Terminalling Services 88,464 88,464 Total $ 202,135 $ 202,135
Schedule of Finite-Lived Intangible Assets	Intangible assets, net, consist of the following (in thousands): September 30, 2017 Gross carrying amount Accumulated amortization Net carrying amount Customer relationships $ 116,345 $ (28,088 ) $ 88,257 Customer contracts 94,693 (46,927 ) 47,766 Dedicated acreage 53,350 (5,773 ) 47,577 Collaborative arrangements 11,884 (1,203 ) 10,681 Noncompete agreements 1,064 (1,064 ) — Other 198 (23 ) 175 Total $ 277,534 $ (83,078 ) $ 194,456 December 31, 2016 Gross carrying amount Accumulated amortization Net carrying amount Customer relationships $ 106,417 $ (23,245 ) $ 83,172 Customer contracts 94,692 (33,228 ) 61,464 Dedicated acreage 53,350 (4,439 ) 48,911 Collaborative arrangements 11,884 (601 ) 11,283 Noncompete agreements 1,063 (1,000 ) 63 Other 198 (20 ) 178 Total $ 267,604 $ (62,533 ) $ 205,071

Investment in Unconsolidated 40

Investment in Unconsolidated Affiliates (Tables)	9 Months Ended
	Sep. 30, 2017
Equity Method Investments and Joint Ventures [Abstract]
Investments in and Advances to Affiliates	The following table presents the activity in our equity method investments in unconsolidated affiliates (in thousands): Delta House (1) Emerald Transactions (2) FPS OGL Destin Tri-States Okeanos Wilprise MPOG (4) Cayenne JV (3) Total Ownership % - 12/31/2016 20.1 % 20.1 % 49.7 % 16.7 % 66.7 % 25.3% 66.7% - Ownership % - 9/30/2017 35.7 % 35.7 % 49.7 % 16.7 % 66.7 % 25.3% - 50.0 % Balances at December 31, 2016 $ 64,483 $ 25,450 $ 110,882 $ 55,022 $ 27,059 $ 4,944 $ 4,147 $ — $ 291,987 Acquisitions 22,539 27,289 — — — — (2,363 ) — 47,465 Earnings in unconsolidated affiliates 23,994 10,589 6,243 3,394 5,706 493 (683 ) 45 49,781 Contributions — — — — — — — 3,770 3,770 Distributions (13,990 ) (12,183 ) (17,334 ) (4,359 ) (9,333 ) (677 ) (1,101 ) — (58,977 ) Balances at September 30, 2017 $ 97,026 $ 51,145 $ 99,791 $ 54,057 $ 23,432 $ 4,760 $ — $ 3,815 $ 334,026 ___________________________________________________ (1) Represents direct and indirect ownership interests in Class A units and common units. (2) Represents our Emerald equity method investments which were acquired in the second quarter of 2016. (3) We formed Cayenne JV effective August 8, 2017. (4) Beginning August 8, 2017, the Partnership consolidated MPOG. See Note 3 - Acquisitions.
Equity Method Investments	The following tables present the summarized combined financial information for our equity investments (amounts represent 100% of investee financial information) (in thousands): Balance Sheets (1) : September 30, 2017 December 31, 2016 Current assets $ 100,400 $ 120,167 Non-current assets 1,294,333 1,369,492 Current liabilities 139,217 133,085 Non-current liabilities $ 422,988 $ 541,312 Three months ended September 30, Nine months ended September 30, Statements of Operations (1) : 2017 2016 2017 2016 Revenue $ 104,904 $ 93,440 $ 304,801 $ 278,720 Gross profit 97,636 83,350 280,996 253,447 Net income $ 77,238 $ 62,775 $ 222,005 $ 199,591 _____________________________________ (1) MPOG was consolidated by us as of August 8, 2017, therefore the tables above do not include MPOG as of September 30, 2017 and for the three and nine months ended September 30, 2017.

Accrued Expenses and Other Cu41

Accrued Expenses and Other Current Liabilities (Tables)	9 Months Ended
	Sep. 30, 2017
Other Liabilities Disclosure [Abstract]
Schedule of Accrued Liabilities	Accrued expenses and other current liabilities consists of the following (in thousands): September 30, 2017 December 31, 2016 Accrued interest $ 9,973 $ 5,743 Taxes payable 7,052 1,186 Current portion of asset retirement obligation 6,416 6,499 Additional Blackwater acquisition consideration 5,000 5,000 Due to related parties 5,115 4,072 Royalties payable 3,548 3,926 Convertible preferred unit distributions 2,871 7,103 Legal accrual 2,783 — Capital expenditures 4,032 14,274 Accrued operating expenses 2,938 — Gas imbalances payable 1,860 1,098 Customer deposits 1,537 148 Employee compensation 1,505 8,438 Transaction costs 736 3,000 Other 12,139 12,234 Total accrued expenses and other current liabilities $ 67,505 $ 72,721

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2017
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	The following table presents activity in our asset retirement obligations for the nine months ended September 30, 2017 (in thousands): Non-current balance $ 44,363 Current balance 6,499 Balances at December 31, 2016 $ 50,862 Additions 6,805 Expenditures (697 ) Accretion expense 1,492 Balances at September 30, 2017 $ 58,462 Less: current portion 6,416 Noncurrent asset retirement obligation $ 52,046

Debt Obligations (Tables)

Debt Obligations (Tables)	9 Months Ended
	Sep. 30, 2017
Debt Disclosure [Abstract]
Outstanding borrowings under the credit facility	Our outstanding debt consists of the following (in thousands): September 30, 2017 December 31, 2016 Revolving credit facility $ 709,652 $ 888,250 8.50% Senior unsecured notes, due 2021 300,000 300,000 3.77% Senior secured notes, due 2031 (non-recourse) 58,649 60,000 Other debt (2) 116 3,762 Total debt obligations 1,068,417 1,252,012 Unamortized debt issuance costs (1) (9,338 ) (11,036 ) Total debt 1,059,079 1,240,976 Less: Current portion, including unamortized debt issuance costs (1,234 ) (5,438 ) Long term debt $ 1,057,845 $ 1,235,538 ___________________________ (1) Unamortized debt issuance costs related to the revolving credit facility are included in our unaudited condensed consolidated balance sheets in Other assets, net. (2) Other debt includes capital lease and miscellaneous long-term obligations, which are reported in Current portion of debt and Other liabilities line items on our unaudited condensed consolidated balance sheets.

Convertible Preferred Units (Ta

Convertible Preferred Units (Tables)	9 Months Ended
	Sep. 30, 2017
Partners' Capital [Abstract]
Schedule of Preferred Units	Our convertible preferred units consist of the following (in thousands): Series A Series C Series D Total Units $ Units $ Units $ $ December 31, 2016 10,107 $ 181,386 8,792 $ 118,229 2,333 $ 34,475 $ 334,090 Paid in kind unit distributions 429 6,645 — 2,844 — — 9,489 September 30, 2017 10,536 $ 188,031 8,792 $ 121,073 2,333 $ 34,475 $ 343,579

Partners Capital (Tables)

Partners Capital (Tables)	9 Months Ended
	Sep. 30, 2017
Equity [Abstract]
Schedule of Units Outstanding and Distributions	We made the following distributions (in thousands): Three months ended September 30, Nine months ended September 30, 2017 2016 2017 2016 Series A Units Cash Paid $ 2,145 $ 2,449 $ 6,790 $ 2,449 Accrued 4,105 4,806 4,105 4,806 Paid-in-kind units 1,924 2,152 6,838 6,623 Series C Units Cash Paid 3,627 1,302 10,880 1,302 Accrued 4,150 3,611 4,150 3,611 Paid-in-kind units — 948 — 948 Series D Units Cash Paid 963 — 2,888 — Accrued — — — — Limited Partner Units Cash Paid 21,345 24,874 67,648 76,656 General Partner Units Cash Paid 277 174 645 2,375 Summary Cash Paid 28,357 28,799 88,851 82,782 Accrued 8,255 8,417 8,255 8,417 Paid-in-kind units 1,924 3,100 6,838 7,571 The following table presents unit activity (in thousands): General Limited Partner Interest Balances at December 31, 2016 680 51,351 LTIP vesting — 460 Issuance of GP units 273 — Issuance of common units (1) — 929 Balances at September 30, 2017 953 52,740 ____________________________________ (1) Including common units issued in connection with the Panther acquisition. See Note 3 - Acquisitions .

Net Loss per Limited Partner 46

Net Loss per Limited Partner Unit (Tables)	9 Months Ended
	Sep. 30, 2017
Earnings Per Share [Abstract]
Schedule of Calculation for Net Loss Per Limited Partner Unit	The calculation of basic and diluted limited partners' net income (loss) per common unit is summarized below (in thousands, except per unit amounts): Three months ended September 30, Nine months ended September 30, 2017 2016 2017 2016 Net income (loss) from continuing operations $ 11,806 $ (5,488 ) $ (42,266 ) $ (35,414 ) Less: Net income attributable to noncontrolling interests 621 1,241 3,386 2,192 Net income (loss) from continuing operations attributable to the Partnership 11,185 (6,729 ) (45,652 ) (37,606 ) Less: Distributions on Series A Units 4,105 4,806 12,472 13,879 Distributions on Series C Units 4,150 3,611 11,403 5,860 Distributions on Series D Units — — 1,925 — General partner's distribution 287 174 763 2,375 General partner's share in undistributed loss (210 ) (375 ) (1,729 ) (1,334 ) Net income (loss) from continuing operations attributable to Limited Partners 2,853 (14,945 ) (70,486 ) (58,386 ) Net income (loss) from discontinued operations attributable to Limited Partners 44,696 (2,310 ) 42,185 7,532 Net income (loss) attributable to Limited Partners $ 47,549 $ (17,255 ) $ (28,301 ) $ (50,854 ) Weighted average number of common units used in computation of Limited Partners' net loss per common unit - basic and diluted 52,021 51,310 52,021 51,310 Limited Partners' net income (loss) from continuing operations per unit $ 0.05 $ (0.29 ) $ (1.35 ) $ (1.14 ) Limited Partners' net income (loss) from discontinued operations per unit 0.86 (0.05 ) 0.81 0.15 Limited Partners' net income (loss) per common unit (1) $ 0.91 $ (0.34 ) $ (0.54 ) $ (0.99 ) _____________________________________ (1) Potential common unit equivalents are antidilutive for all periods presented and, as a result, have been excluded from the determination of diluted limited partners' net loss per common unit.

Long-Term Incentive Plan (Table

Long-Term Incentive Plan (Tables)	9 Months Ended
	Sep. 30, 2017
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 nine months ended September 30, 2017 : Units Weighted-Average Grant Date Fair Value Per Unit Outstanding units at December 31, 2016 1,558,835 $ 6.98 Granted 2,000 11.20 Forfeited (18,919 ) 13.49 Vested (570,038 ) 11.13 Outstanding units at September 30, 2017 971,878 $ 4.43

Supplemental Cash Flow Inform48

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2017
Supplemental Cash Flow Elements [Abstract]
Schedule of Supplemental Cash Flow Information	Supplemental cash flows and non-cash transactions consist of the following (in thousands): Nine months ended September 30, 2017 2016 Supplemental non-cash information Investing Increase (decrease) in accrued property, plant and equipment purchases $ (15,112 ) $ 4,597 Financing Issuance of common units for the Panther acquisition 12,532 — Contributions from an affiliate holding limited partner interests 4,000 7,500 Issuance of Series C Units and Warrant in connection with the Emerald Transactions — 120,000 Accrued distributions on convertible preferred units 8,255 8,417 Paid-in-kind distributions on convertible preferred units 6,838 7,571 Cancellation of escrow units — 6,817 Accrued distribution from unconsolidated affiliates — 5,000

Reportable Segments (Tables)

Reportable Segments (Tables)	9 Months Ended
	Sep. 30, 2017
Segment Reporting [Abstract]
Segment information	A reconciliation from Total segment gross margin to Net income (loss) attributable to the Partnership for the periods presented is below (in thousands): Three months ended September 30, Nine months ended September 30, 2017 2016 2017 2016 Reconciliation of Segment Gross Margin to Net income (loss) attributable to the Partnership: Gas Gathering and Processing Services segment gross margin $ 12,761 $ 12,627 $ 36,663 $ 37,586 Liquid Pipelines and Services segment gross margin 7,808 7,600 21,209 23,829 Natural Gas Transportation Services segment gross margin 5,356 3,709 17,106 13,115 Offshore Pipelines and Services segment gross margin 29,312 24,126 80,738 57,947 Terminalling Services segment gross margin (1) 8,509 10,731 30,429 31,760 Total segment gross margin (non-GAAP) 63,746 58,793 186,145 164,237 Less: Direct operating expenses (1) 17,274 14,695 47,316 45,999 Plus: Gain (loss) on commodity derivatives, net (597 ) 324 (33 ) (1,929 ) Less: Corporate expenses 27,083 22,103 84,570 60,945 Depreciation, amortization and accretion expense 26,781 22,668 78,834 65,937 (Gain) loss on sale of assets, net (4,061 ) 36 (4,064 ) 297 Interest expense 17,759 5,830 51,037 24,723 Other (income) expense (34,085 ) 1 (32,248 ) (245 ) Other (income) expense, net (139 ) (1,129 ) 322 (1,773 ) Income tax expense 731 401 2,611 1,839 (Income) loss from discontinued operations, net of tax (44,696 ) 2,310 (42,185 ) (7,532 ) Net income attributable to noncontrolling interests 621 1,241 3,386 2,192 Net income (loss) $ 55,881 $ (9,039 ) $ (3,467 ) $ (30,074 ) _____________________________________ (1) Direct operating expenses include Gas Gathering and Processing Services segment direct operating expenses of $8.7 million and $7.9 million , Liquid Pipelines and Services segment direct operating expenses of $2.4 million and $2.6 million , Natural Gas Transportation Services segment direct operating expenses of $2.2 million and $1.3 million and Offshore Pipelines and Services segment direct operating expenses of $3.9 million and $2.9 million for the three months ended September 30, 2017 and 2016 , respectively. Direct operating expenses related to our Terminalling Services segment of $3.4 million and $2.9 million for the three months ended September 30, 2017 and 2016 , respectively, are included within the calculation of Terminalling Services segment gross margin. Other direct operating expenses include Gas Gathering and Processing Services segment direct operating expenses of $24.8 million and $25.3 million , Liquid Pipelines and Services segment direct operating expenses of $7.1 million and $8.2 million , Natural Gas Transportation Services segment direct operating expenses of $5.4 million and $4.5 million , and Offshore Pipelines and Services segment direct operating expenses of $10.0 million and $8.0 million for the nine months ended September 30, 2017 and 2016 , respectively. Direct operating expenses related to our Terminalling Services segment of $9.5 million and $7.9 million for the nine months ended September 30, 2017 and 2016 , respectively, are included within the calculation of Terminalling Services segment gross margin. The following tables set forth our segment information for the three and nine months ended September 30, 2017 and 2016 (in thousands): Three months ended September 30, 2017 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 37,287 $ 87,022 $ 11,131 $ 14,360 $ 13,087 $ 162,887 Gain (loss) on commodity derivatives, net (65 ) (532 ) — — — (597 ) Total revenue 37,222 86,490 11,131 14,360 13,087 162,290 Earnings in unconsolidated affiliates — 1,317 — 15,510 — 16,827 Operating expenses: Cost of Sales 24,492 80,510 5,692 558 1,146 112,398 Direct operating expenses 8,655 2,438 2,240 3,940 3,432 20,705 Corporate expenses 27,083 Depreciation, amortization and accretion expense 26,781 Gain on sale of assets, net (4,061 ) Total operating expenses 182,906 Interest expense 17,759 Other income (34,085 ) Income from continuing operations before income taxes 12,537 Income tax expense 731 Income from continuing operations 11,806 Income from discontinued operations, including gain on disposition (Note 4) 44,696 Net income 56,502 Less: Net income attributable to non-controlling interests 621 Net income attributable to the Partnership $ 55,881 Segment gross margin $ 12,761 $ 7,808 $ 5,356 $ 29,312 $ 8,509 Three months ended September 30, 2016 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 31,650 $ 87,898 $ 10,709 $ 14,879 $ 14,443 $ 159,579 Gain (loss) on commodity derivatives, net 149 177 — (2 ) — — 324 Total revenue 31,799 88,075 10,709 14,877 14,443 159,903 Earnings in unconsolidated affiliates (1 ) 650 — 9,819 — 10,468 Operating expenses: Cost of Sales 18,477 80,372 6,994 570 836 107,249 Direct operating expenses 7,856 2,617 1,324 2,898 2,876 17,571 Corporate expenses 22,103 Depreciation, amortization and accretion expense 22,668 Loss on sale of assets, net 36 Total operating expenses 169,627 Interest expense 5,830 Other expense 1 Loss from continuing operations before income taxes (5,087 ) Income tax expense 401 Loss from continuing operations (5,488 ) Loss from discontinued operations (2,310 ) Net loss (7,798 ) Less: Net income attributable to non-controlling interests 1,241 Net loss attributable to the Partnership $ (9,039 ) Segment gross margin $ 12,627 $ 7,600 $ 3,709 $ 24,126 $ 10,731 Nine months ended September 30, 2017 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 111,001 $ 253,590 $ 34,966 $ 41,330 $ 47,544 $ 488,431 Gain (loss) on commodity derivatives, net (170 ) 137 — — — (33 ) Total revenue 110,831 253,727 34,966 41,330 47,544 488,398 Earnings in unconsolidated affiliates — 3,886 — 45,895 — 49,781 Operating expenses: Cost of Sales 74,261 236,896 17,630 6,487 7,612 342,886 Direct operating expenses 24,766 7,137 5,403 10,010 9,503 56,819 Corporate expenses 84,570 Depreciation, amortization and accretion expense 78,834 Gain on sale of assets, net (4,064 ) Total operating expenses 559,045 Interest expense 51,037 Other income (32,248 ) Loss from continuing operations before income taxes (39,655 ) Income tax expense 2,611 Loss from continuing operations (42,266 ) Income from discontinued operations, including gain on disposition (Note 4) 42,185 Net loss (81 ) Less: Net income attributable to non-controlling interests 3,386 Net loss attributable to the Partnership $ (3,467 ) Segment gross margin $ 36,663 $ 21,209 $ 17,106 $ 80,738 $ 30,429 Nine months ended September 30, 2016 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 85,655 $ 221,866 $ 28,383 $ 32,526 $ 46,652 $ 415,082 Gain (loss) on commodity derivatives, net (716 ) (772 ) — (5 ) (436 ) (1,929 ) Total revenue 84,939 221,094 28,383 32,521 46,216 413,153 Earnings in unconsolidated affiliates — 1,658 — 27,855 — 29,513 Operating expenses: Cost of Sales 47,344 199,111 15,245 2,429 6,583 270,712 Direct operating expenses 25,344 8,186 4,515 7,954 7,873 53,872 Corporate expenses 60,945 Depreciation, amortization and accretion expense 65,937 Loss on sale of assets, net 297 Total operating expenses 451,763 Interest expense 24,723 Other income (245 ) Loss from continuing operations before income taxes (33,575 ) Income tax expense 1,839 Loss from continuing operations (35,414 ) Income from discontinued operations 7,532 Net loss (27,882 ) Less: Net income attributable to non-controlling interests 2,192 Net loss attributable to the Partnership $ (30,074 ) Segment gross margin $ 37,586 $ 23,829 $ 13,115 $ 57,947 $ 31,760 A reconciliation of total assets by segment to the amounts included in the condensed consolidated balance sheets follows: September 30, December 31, 2017 2016 Segment assets: Gas Gathering and Processing Services $ 416,498 $ 530,889 Liquid Pipelines and Services 443,771 425,389 Offshore Pipelines and Services 544,895 400,193 Natural Gas Transportation Services 172,813 221,604 Terminalling Services 256,922 299,534 Other (1) 188,308 334,953 Discontinued Operations — 136,759 Total Assets $ 2,023,207 $ 2,349,321 _____________________________________ (1) Other assets not allocable to segments consist of corporate leasehold improvements and other miscellaneous assets.

Organization, Basis of Presen50

Organization, Basis of Presentation and Summary of Significant Accounting Policies (Details) shares in Millions, $ in Millions	9 Months Ended
	Sep. 30, 2017USD ($)segments	Mar. 08, 2017shares	Dec. 31, 2016USD ($)	Dec. 28, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments | segments	5
Debt Instrument [Line Items]
General partners' capital account, percentage	77.00%
Limited partners' capital account, percentage	23.00%
Allowance for doubtful accounts receivable | $	$ 0.1		$ 0.6
Senior Notes [Member] | 8.50% Senior Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	8.50%	8.50%	8.50%	8.50%
JPE Energy Partners [Member]
Debt Instrument [Line Items]
General partner interest, units issued (in shares)		20.2
JPE Energy Partners [Member] | Affiliated Entity [Member]
Debt Instrument [Line Items]
General partner interest, units issued (in shares)		9.8

Acquisitions (JP Energy Partner

Acquisitions (JP Energy Partners LP Narrative) (Details) shares in Millions	Mar. 08, 2017shares
Affiliated Holders [Member]
Business Acquisition [Line Items]
Merger agreement, conversion ratio	0.5775
Public Unit Consideration [Member]
Business Acquisition [Line Items]
Merger agreement, conversion ratio	0.5225
General Partner [Member]
Business Acquisition [Line Items]
General partner interest, units issued (in shares)	20.2
Affiliated Entity [Member] | General Partner [Member]
Business Acquisition [Line Items]
General partner interest, units issued (in shares)	9.8

Acquisitions (Viosca Knoll Narr

Acquisitions (Viosca Knoll Narrative) (Details) - USD ($) $ in Millions	Jun. 02, 2017	Sep. 30, 2017	Aug. 08, 2017
Viosca Knoll [Member]
Business Acquisition [Line Items]
Equity interests acquired (percent)	100.00%
Total consideration upon acquisition	$ 32
Reclassification to Property, plant and equipment		$ 3.3
Reclassification from Intangibles		$ 3.4
AmPan [Member]
Business Acquisition [Line Items]
Equity interests acquired (percent)			100.00%

Acquisitions (Allocation of Vio

Acquisitions (Allocation of Viosca Knoll Purchase Price) (Details) - Viosca Knoll [Member] $ in Thousands	Sep. 30, 2017USD ($)
Business Acquisition [Line Items]
Total property, plant and equipment	$ 32,286
Liability	(286)
Total cash consideration	32,000
Pipelines and right-of-way [Member]
Business Acquisition [Line Items]
Total property, plant and equipment	13,433
Equipment [Member]
Business Acquisition [Line Items]
Total property, plant and equipment	$ 18,853

Acquisitions (Acquisition of Pa

Acquisitions (Acquisition of Panther) (Details) mi in Thousands, $ in Thousands	Aug. 08, 2017USD ($)mi	Sep. 30, 2017USD ($)
Business Acquisition [Line Items]
Acquisition of noncontrolling interest		$ 28,298
Panther Asset Management LLC (Panther) [Member]
Business Acquisition [Line Items]
Equity interests acquired (percent)	100.00%
Total consideration upon acquisition	$ 57,200
Cash payment made to acquire business	39,100
Value of partnership interest issued	$ 12,500
Length of pipeline | mi	1
MPOG [Member]
Business Acquisition [Line Items]
Current ownership interest (percent)	100.00%
Fair value remeasurement gain (loss)	$ 32,300
AmPan [Member]
Business Acquisition [Line Items]
Equity interests acquired (percent)	100.00%
Acquisition of noncontrolling interest	$ 28,300
Matagorda System [Member]
Business Acquisition [Line Items]
Ownership interest acquired (percent)	50.00%
Noncontrolling Interest [Member]
Business Acquisition [Line Items]
Acquisition of noncontrolling interest		$ 4,645
Noncontrolling Interest [Member] | AmPan [Member]
Business Acquisition [Line Items]
Acquisition of noncontrolling interest	$ 4,600

Acquisitions (Panther Purchase

Acquisitions (Panther Purchase Price Allocation) (Details) - Panther Asset Management LLC (Panther) [Member] $ in Thousands	Sep. 30, 2017USD ($)
Business Acquisition [Line Items]
Fair value of acquired noncontrolling interest	$ 28,298
Total property, plant and equipment	16,870
Intangible assets	9,989
Net working capital, net of cash acquired	2,410
Other	2,975
Asset retirement obligation	(3,367)
Total cash consideration	$ 57,175

Discontinued Operations (Narrat

Discontinued Operations (Narrative) (Details) $ in Thousands	Sep. 01, 2017USD ($)location	Sep. 30, 2017USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2017USD ($)	Sep. 30, 2016USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of business and assets, net of cash on hand				$ 167,979	$ 11,761
Closing adjustments				2,500
Income (loss) from discontinued operations, including net gain on disposition of $46.5 million (Note 4)		$ 44,696	$ (2,310)	42,185	7,532
Propane Marketing Services [Member] | Discontinued Operations, Disposed of by Sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of assets divested (percent)	100.00%
Proceeds from sale of business and assets, net of cash on hand	$ 170,000
Gain on sale of Propane business	46,500
Closing adjustments	$ 2,500
Income (loss) from discontinued operations, including net gain on disposition of $46.5 million (Note 4)		(1,849)	(2,310)	(4,360)	8,071
Income tax		15	0	59	(2)
Partnership’s income (loss) from discontinued operations		$ 44,696	$ (2,310)	$ 42,185	$ 8,071
Propane Business [Member] | Propane Marketing Services [Member] | Discontinued Operations, Disposed of by Sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Number of service locations divested | location	40

Discontinued Operations (Conden

Discontinued Operations (Condensed Balance Sheets) (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Current assets of discontinued operations	$ 0	$ 22,727
Total noncurrent assets of discontinued operations	0	114,032
Current liabilities of discontinued operations	$ 0	14,319
Propane Marketing Services [Member] | Discontinued Operations, Disposed of by Sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Current assets of discontinued operations		22,727
Total noncurrent assets of discontinued operations		114,032
Total assets of discontinued operations		136,759
Current liabilities of discontinued operations		14,319
Other long-term liabilities of discontinued operations		172
Total liabilities of discontinued operations		$ 14,491

Discontinued Operations (Cond58

Discontinued Operations (Condensed Statements of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income (loss) from discontinued operations	$ 44,696	$ (2,310)	$ 42,185	$ 7,532
Gain from the sale of discontinued operations	44,696	(2,310)	42,185	7,532
Propane Marketing Services [Member] | Discontinued Operations, Disposed of by Sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total revenue	20,458	27,756	87,615	103,718
Total operating expenses	22,489	30,158	92,196	96,003
Income (loss) from discontinued operations before taxes	(1,834)	(2,310)	(4,301)	8,069
Income tax benefit (expense)	(15)	0	(59)	2
Income (loss) from discontinued operations	(1,849)	(2,310)	(4,360)	8,071
Gain from the sale of discontinued operations	46,545	0	46,545	0
Partnership’s income (loss) from discontinued operations, including gain on sale.	$ 44,696	$ (2,310)	$ 42,185	8,071
Mid Continent Business [Member] | Discontinued Operations, Disposed of by Sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total revenue				11,500
Total operating expenses				12,000
Income (loss) from discontinued operations				$ 500

Discontinued Operations (Other

Discontinued Operations (Other Selected Financial Information) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Other operating and investing non-cash items related to discontinued operations:
(Gain) loss on sales of assets, net	$ 118	$ 725	$ (55)	$ 2,064
Unrealized (gain) loss on derivatives contracts, net	(526)	106	530	(628)
Propane Marketing Services [Member] | Discontinued Operations, Disposed of by Sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Depreciation and amortization	2,355	3,850	9,823	12,020
Capital expenditures	$ 722	$ 1,483	$ 3,143	$ 3,451

Inventory (Details)

Inventory (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Inventory Disclosure [Abstract]
Crude oil	$ 4,565	$ 1,216
NGLs	232	288
Refined products	674	0
Materials, supplies and equipment	499	486
Total inventory	$ 5,970	$ 1,990

Other Current Assets (Details)

Other Current Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Prepaid insurance	$ 1,428	$ 9,702
Insurance receivables	3,728	1,624
Due from related parties	5,062	4,833
Other receivables	2,768	2,997
Risk management assets	1,827	469
Other assets	2,331	5,891
Total other current assets	$ 17,144	$ 25,516

Risk Management Activities (Com

Risk Management Activities (Commodity-related Derivatives) (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2017bblgal	Dec. 31, 2016bblgal
Propane [Member] | Propane, Fixed Price Commodity Swap Contract [Member]
Derivative [Line Items]
Derivative, volume | gal	819,000,000
Crude Oil [Member] | Crude Oil, Fixed Price Commodity Swap Contract [Member]
Derivative [Line Items]
Derivative, volume	125,000,000	0
Crude Oil [Member] | Propane, Basis Commodity Swap Contract [Member]
Derivative [Line Items]
Derivative, volume	0	180,000,000

Risk Management Activities (Int

Risk Management Activities (Interest Rate Swaps) (Details) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Interest Rate Swap [Member]
Derivative [Line Items]
Notional Amount	$ 650	$ 650

Risk Management Activities (Nar

Risk Management Activities (Narrative) (Details) - Weather Contract [Member] - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Derivative [Line Items]
Potential proceeds from derivative contract	$ 30
Payment for weather derivative premium		$ 1.1	$ 1
Term of contract		1 year
Debt instrument, unamortized premium	$ 0.8	$ 0.8		$ 0.4

Risk Management Activities (Fai

Risk Management Activities (Fair Value of Commodity Derivatives) (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Derivative Asset [Abstract]
Gross Risk Management Position	$ 9,639	$ 11,169
Netting Adjustments	(267)	(73)
Net Risk Management Position	9,372	11,096
Derivative Liability [Abstract]
Gross Risk Management Position	(653)	(254)
Netting Adjustments	267	73
Net Risk Management Position	(386)	(181)
Other Current Assets [Member] | Commodity derivatives [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	267	112
Derivative Liability [Abstract]
Gross Risk Management Position	0	0
Other Current Assets [Member] | Interest Rate Swap [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	1,041
Other Current Assets [Member] | Weather Derivative [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	786	429
Derivative Liability [Abstract]
Gross Risk Management Position	0	0
Accrued Expenses and Other Liabilities [Member] | Commodity derivatives [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	0	0
Derivative Liability [Abstract]
Gross Risk Management Position	(653)	(1)
Accrued Expenses and Other Liabilities [Member] | Interest Rate Swap [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	0	0
Derivative Liability [Abstract]
Gross Risk Management Position	0	(252)
Risk Management Assets [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	2,094	541
Netting Adjustments	(267)	(72)
Net Risk Management Position	1,827	469
Risk Management Assets - Long Term [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	7,545	10,628
Netting Adjustments	0	(1)
Net Risk Management Position	7,545	10,627
Risk Management Assets - Long Term [Member] | Interest Rate Swap [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	7,545	10,628
Derivative Liability [Abstract]
Gross Risk Management Position	0	0
Other Liabilities [Member] | Commodity derivatives [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	0	0
Derivative Liability [Abstract]
Gross Risk Management Position	0	(1)
Risk Management Liabilities [Member]
Derivative Liability [Abstract]
Gross Risk Management Position	(653)	(253)
Netting Adjustments	267	72
Net Risk Management Position	(386)	(181)
Risk Management Liabilities - Long Term [Member]
Derivative Liability [Abstract]
Gross Risk Management Position	0	(1)
Netting Adjustments	0	1
Net Risk Management Position	$ 0	$ 0

Risk Management Activities (Rea

Risk Management Activities (Realized and Unrealized Gains (Losses)) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Derivatives, Fair Value [Line Items]
Gain (loss) on commodity derivatives, net	$ (597)	$ 324	$ (33)	$ (1,929)
Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Gain (loss) on commodity derivatives, net	(278)	(1,074)	(307)	(2,246)
Unrealized gain (loss) on derivatives	(325)	3,175	(2,288)	(2,431)
Commodity derivatives [Member] | Gain (Loss) on Derivative Instruments [Member]
Derivatives, Fair Value [Line Items]
Gain (loss) on commodity derivatives, net	(51)	(742)	465	(1,432)
Unrealized gain (loss) on derivatives	(546)	1,066	(498)	(497)
Commodity derivatives [Member] | Interest Expense [Member]
Derivatives, Fair Value [Line Items]
Gain (loss) on commodity derivatives, net	51	(75)	(19)	(106)
Unrealized gain (loss) on derivatives	221	2,109	(1,790)	(1,934)
Commodity derivatives [Member] | Direct operating expenses [Member]
Derivatives, Fair Value [Line Items]
Gain (loss) on commodity derivatives, net	(278)	(257)	(753)	(708)
Unrealized gain (loss) on derivatives	$ 0	$ 0	$ 0	$ 0

Property, Plant and Equipment67

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Dec. 31, 2016
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	$ 1,461,476	$ 1,331,330
Accumulated depreciation	(320,650)	(264,722)
Property, plant and equipment, net	1,140,826	1,066,608
Land [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	18,440	18,861
Construction in progress [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	81,133	128,519
Buildings and improvements [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	13,782	13,762
Transportation equipment [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	22,743	20,010
Processing and treating plants [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	141,334	120,977
Pipelines, compressors and right-of-way [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	958,004	804,815
Storage [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	146,473	146,408
Equipment [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	$ 79,567	$ 77,978
Minimum [Member] | Buildings and improvements [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life	4 years
Minimum [Member] | Transportation equipment [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life	5 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, compressors and right-of-way [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life	3 years
Minimum [Member] | Storage [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	3 years
Maximum [Member] | Buildings and improvements [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life	40 years
Maximum [Member] | Transportation equipment [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life	15 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, compressors and right-of-way [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life	40 years
Maximum [Member] | Storage [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	31 years

Property, Plant and Equipment68

Property, Plant and Equipment (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	$ 1,461,476		$ 1,461,476		$ 1,331,330
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	320,650		320,650		264,722
Depreciation	20,100	$ 17,800	56,900	$ 51,600
Interest costs capitalized	500	$ 700	2,000	$ 1,700
FERC Regulated Assets [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	314,800		314,800		291,100
Processing And Treating Plants [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	141,334		141,334		120,977
Pipelines [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	$ 958,004		$ 958,004		$ 804,815

Goodwill and Intangible Asset69

Goodwill and Intangible Assets (Schedule of Goodwill) (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Goodwill [Line Items]
Goodwill	$ 202,135	$ 202,135
Liquid Pipelines and Services [Member]
Goodwill [Line Items]
Goodwill	113,671	113,671
Terminalling Services [Member]
Goodwill [Line Items]
Goodwill	$ 88,464	$ 88,464

Goodwill and Intangible Asset70

Goodwill and Intangible Assets Goodwill and Intangible Assets (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 5.1	$ 4.4	$ 20.6	$ 13.3
Minimum [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived intangible asset, useful life			5 years
Maximum [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived intangible asset, useful life			44 years

Goodwill and Intangible Asset71

Goodwill and Intangible Assets Schedule of Intangible Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Finite-Lived Intangible Assets [Line Items]
Customer relationships	$ 277,534	$ 267,604
Finite-Lived Intangible Assets, Accumulated Amortization	(83,078)	(62,533)
Finite-Lived Intangible Assets, Net	194,456	205,071
Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Customer relationships	116,345	106,417
Finite-Lived Intangible Assets, Accumulated Amortization	(28,088)	(23,245)
Finite-Lived Intangible Assets, Net	88,257	83,172
Customer Contracts [Member]
Finite-Lived Intangible Assets [Line Items]
Customer relationships	94,693	94,692
Finite-Lived Intangible Assets, Accumulated Amortization	(46,927)	(33,228)
Finite-Lived Intangible Assets, Net	47,766	61,464
Dedicated Acreage [Member]
Finite-Lived Intangible Assets [Line Items]
Customer relationships	53,350	53,350
Finite-Lived Intangible Assets, Accumulated Amortization	(5,773)	(4,439)
Finite-Lived Intangible Assets, Net	47,577	48,911
Collaborative Arrangement [Member]
Finite-Lived Intangible Assets [Line Items]
Customer relationships	11,884	11,884
Finite-Lived Intangible Assets, Accumulated Amortization	(1,203)	(601)
Finite-Lived Intangible Assets, Net	10,681	11,283
Noncompete Agreements [Member]
Finite-Lived Intangible Assets [Line Items]
Customer relationships	1,064	1,063
Finite-Lived Intangible Assets, Accumulated Amortization	(1,064)	(1,000)
Finite-Lived Intangible Assets, Net	0	63
Other Intangible Assets [Member]
Finite-Lived Intangible Assets [Line Items]
Customer relationships	198	198
Finite-Lived Intangible Assets, Accumulated Amortization	(23)	(20)
Finite-Lived Intangible Assets, Net	$ 175	$ 178

Investment in Unconsolidated 72

Investment in Unconsolidated Affiliates - Narrative (Details) - USD ($) $ in Thousands	Sep. 29, 2017	Aug. 08, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates			$ 334,026		$ 334,026		$ 291,987
General partner's distribution					94,120	$ 103,771
Earnings in unconsolidated affiliates			$ 16,827	$ 10,468	49,781	29,513
Distributions from unconsolidated affiliates					$ 49,781	$ 29,513
Cayenne JV [Member]
Schedule of Equity Method Investments [Line Items]
Proceeds from sale of interest		$ 5,000
Economic interest (percent)		50.00%
Voting rights (percent)		50.00%
Ownership interest acquired (percent)			50.00%		50.00%
Earnings in unconsolidated affiliates					$ 45
Delta House [Member]
Schedule of Equity Method Investments [Line Items]
Equity interests acquired (percent)	15.50%
Consideration paid to acquire interest in joint venture	$ 125,400
Ownership interest acquired (percent)	35.70%
Investments in unconsolidated affiliates	$ 49,800
General partner's distribution	$ 75,600
Earnings in unconsolidated affiliates			$ 12,500		34,600
Distributions from unconsolidated affiliates			$ 10,300		$ 26,200
Targa Midstream Services, LLC (Targa) [Member] | Cayenne JV [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest sold (percent)		50.00%
Arclight [Member] | Delta House [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest acquired (percent)	23.30%

Investment in Unconsolidated 73

Investment in Unconsolidated Affiliates Partnership's Equity Investments (Details) - USD ($) $ in Thousands	Aug. 08, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 291,987
Acquisitions				47,465
Earnings in unconsolidated affiliates		$ 16,827	$ 10,468	49,781	$ 29,513
Cash Call For Expansion Projects				3,770
Distributions				(58,977)
Balances		$ 334,026		$ 334,026
FPS [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)		35.70%		35.70%		20.10%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 64,483
Acquisitions				22,539
Earnings in unconsolidated affiliates				23,994
Cash Call For Expansion Projects				0
Distributions				(13,990)
Balances		$ 97,026		$ 97,026
OGL [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)		35.70%		35.70%		20.10%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 25,450
Acquisitions				27,289
Earnings in unconsolidated affiliates				10,589
Cash Call For Expansion Projects				0
Distributions				(12,183)
Balances		$ 51,145		$ 51,145
Destin [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)		49.70%		49.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 110,882
Acquisitions				0
Earnings in unconsolidated affiliates				6,243
Cash Call For Expansion Projects				0
Distributions				(17,334)
Balances		$ 99,791		$ 99,791
Tri-State [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)		16.70%		16.70%		16.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 55,022
Acquisitions				0
Earnings in unconsolidated affiliates				3,394
Cash Call For Expansion Projects				0
Distributions				(4,359)
Balances		$ 54,057		$ 54,057
Okeanos [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)		66.70%		66.70%		66.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 27,059
Acquisitions				0
Earnings in unconsolidated affiliates				5,706
Cash Call For Expansion Projects				0
Distributions				(9,333)
Balances		$ 23,432		$ 23,432
Wilprise [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)		25.30%		25.30%		25.30%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 4,944
Acquisitions				0
Earnings in unconsolidated affiliates				493
Cash Call For Expansion Projects				0
Distributions				(677)
Balances		$ 4,760		4,760
MPOG [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)						66.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				4,147
Acquisitions				(2,363)
Earnings in unconsolidated affiliates				(683)
Cash Call For Expansion Projects				0
Distributions				(1,101)
Balances		$ 0		$ 0
Cayenne JV [Member]
Schedule of Equity Method Investments [Line Items]
Proceeds from sale of interest	$ 5,000
Ownership interest (percent)		50.00%		50.00%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances				$ 0
Acquisitions				0
Earnings in unconsolidated affiliates				45
Cash Call For Expansion Projects				3,770
Distributions				0
Balances		$ 3,815		$ 3,815
Targa Midstream Services, LLC (Targa) [Member] | Cayenne JV [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest sold (percent)	50.00%

Investment in Unconsolidated 74

Investment in Unconsolidated Affiliates Financial Information for the Partnership's Equity Investments - Balance Sheets (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
Current assets	$ 100,400	$ 120,167
Non-current assets	1,294,333	1,369,492
Current liabilities	139,217	133,085
Non-current liabilities	$ 422,988	$ 541,312

Investment in Unconsolidated 75

Investment in Unconsolidated Affiliates Financial Information for the Partnership's Equity Investments - Statement of Operations (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Revenue	$ 104,904	$ 93,440	$ 304,801	$ 278,720
Gross profit	97,636	83,350	280,996	253,447
Net income	$ 77,238	$ 62,775	$ 222,005	$ 199,591

Accrued Expenses and Other Cu76

Accrued Expenses and Other Current Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Other Liabilities Disclosure [Abstract]
Accrued interest	$ 9,973	$ 5,743
Taxes payable	7,052	1,186
Current portion of asset retirement obligation	6,416	6,499
Additional Blackwater acquisition consideration	5,000	5,000
Due to related parties	5,115	4,072
Royalties payable	3,548	3,926
Convertible preferred unit distributions	2,871	7,103
Legal accrual	2,783	0
Capital expenditures	4,032	14,274
Accrued operating expenses	2,938	0
Gas imbalances payable	1,860	1,098
Customer deposits	1,537	148
Employee compensation	1,505	8,438
Transaction costs	736	3,000
Other	12,139	12,234
Total accrued expenses and other current liabilities	$ 67,505	$ 72,721

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2017	Dec. 31, 2016
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Non-current balance	$ 44,363
Current portion of asset retirement obligation	6,499
Balances at December 31, 2016	50,862
Additions	6,805
Expenditures	(697)
Accretion expense	1,492
Balances at September 30, 2017	50,862	$ 58,462	$ 50,862
Less: current portion	6,416
Noncurrent asset retirement obligation	$ 52,046
Restricted cash and cash equivalents		$ 5,000	$ 5,000

Debt Obligations (Details)

Debt Obligations (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Mar. 08, 2017	Dec. 31, 2016	Dec. 28, 2016	Sep. 30, 2016
Debt Instrument [Line Items]
Revolving credit facility	$ 709,652		$ 888,250
Long-term	1,068,417		1,252,012
Unamortized debt issuance costs	(9,338)		(11,036)
Total debt obligations	1,059,079		1,240,976
Less: current portion	(1,234)		(5,438)
Long-term debt	1,057,845		1,235,538
Senior Notes [Member] | 8.50% Senior Notes [Member]
Debt Instrument [Line Items]
Long-term	$ 300,000		$ 300,000
Debt instrument, interest rate, stated percentage	8.50%	8.50%	8.50%	8.50%
Senior Notes [Member] | 3.77% Senior Notes [Member]
Debt Instrument [Line Items]
Long-term	$ 58,649		$ 60,000
Debt instrument, interest rate, stated percentage	3.77%		3.77%		3.77%
Other Debt Obligations [Member]
Debt Instrument [Line Items]
Long-term	$ 116		$ 3,762
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Revolving credit facility	$ 709,652		$ 888,250

Debt Obligations (Narrative) (D

Debt Obligations (Narrative) (Details)	Mar. 08, 2017USD ($)	Dec. 28, 2016USD ($)	Sep. 30, 2017USD ($)	Sep. 30, 2016USD ($)	Dec. 31, 2016USD ($)	Apr. 25, 2016USD ($)
Debt Instrument [Line Items]
Letters of credit outstanding, amount			$ 33,100,000		$ 7,400,000
Repayments of lines of credit			546,408,000	$ 172,650,000
Other			$ 86,000	$ (188,000)
8.50% Senior Notes [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	8.50%	8.50%	8.50%		8.50%
Proceeds from debt issuance		$ 294,000,000
Debt issuance costs		6,000,000
Debt instrument, face amount		$ 300,000,000
Senior Notes, Due 2021 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			8.50%
Fair value, debt			$ 310,200,000
3.77% Senior Notes [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			3.77%	3.77%	3.77%
Fair value, debt			$ 55,400,000
Debt instrument, interest coverage ratio				1.20
Debt instrument, face amount				$ 60,000,000
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of credit facility, current borrowing capacity	$ 900,000,000					$ 750,000,000
Line of credit facility, maximum borrowing capacity	$ 1,100,000,000
Line of credit facility, unused capacity, commitment fee percentage			0.50%
Adjusted consolidated EBITDA	5		5.50
Consolidated secured leverage ratio			3.50
Debt instrument, interest coverage ratio			4.41
Debt, weighted average interest rate			4.85%	2.82%
Consolidated total leverage ratio			4.68
Interest coverage ratio			2.50
Revolving Credit Facility [Member] | Base Rate [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			3.25%
Revolving Credit Facility [Member] | Base Rate [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			2.00%
Revolving Credit Facility [Member] | Federal Funds [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			0.50%
Revolving Credit Facility [Member] | Eurodollar [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			1.00%
Revolving Credit Facility [Member] | Eurodollar [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			2.25%
Revolving Credit Facility [Member] | Eurodollar [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			1.00%
JPE [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity			$ 275,000,000
JPE [Member] | Letter of Credit [Member]
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity			$ 100,000,000
Repayments of lines of credit	$ 199,500,000

Convertible Preferred Units (Sc

Convertible Preferred Units (Schedule of Convertible Preferred Units) (Details) - USD ($) shares in Thousands, $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Increase (Decrease) in Partners' Capital [Roll Forward]
Convertible preferred units, Beginning Balance, Amount,	$ 334,090
Paid in kind unit distributions, Amount	94,120	$ 103,771
Convertible preferred units, Ending Balance, Amount,	343,579
Unit Distribution [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Paid in kind unit distributions, Amount	$ 9,489
Series A [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Convertible preferred units, Beginning Balance, Units	10,107
Convertible preferred units, Ending Balance, Units	10,536
Convertible preferred units, Beginning Balance, Amount,	$ 181,386
Convertible preferred units, Ending Balance, Amount,	$ 188,031
Series A [Member] | Unit Distribution [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Paid in kind unit distributions, Units	429
Paid in kind unit distributions, Amount	$ 6,645
Series C [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Convertible preferred units, Beginning Balance, Units	8,792
Convertible preferred units, Ending Balance, Units	8,792
Convertible preferred units, Beginning Balance, Amount,	$ 118,229
Convertible preferred units, Ending Balance, Amount,	$ 121,073
Series C [Member] | Unit Distribution [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Paid in kind unit distributions, Units	0
Paid in kind unit distributions, Amount	$ 2,844
Series D [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Convertible preferred units, Beginning Balance, Units	2,333
Convertible preferred units, Ending Balance, Units	2,333
Convertible preferred units, Beginning Balance, Amount,	$ 34,475
Convertible preferred units, Ending Balance, Amount,	$ 34,475
Series D [Member] | Unit Distribution [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Paid in kind unit distributions, Units	0
Paid in kind unit distributions, Amount	$ 0

Convertible Preferred Units (De

Convertible Preferred Units (Details) - USD ($)		Oct. 26, 2017	Apr. 25, 2016	Jul. 27, 2015	Apr. 15, 2013	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2015	Oct. 02, 2017	Mar. 08, 2017	Dec. 31, 2016	Oct. 31, 2016
Preferred Units [Line Items]
Distribution declared per common unit (in usd per share)	[1]					$ 0.4125	$ 0.4125	$ 1.2375	$ 1.2975
Issuance of warrant									$ 4,481,000
Preferred, units, outstanding (in shares)						52,740,000		52,740,000					51,351,000
Series A [Member]
Preferred Units [Line Items]
Sale of units percentage					90.00%
Partners' Capital Account, Units					5,142,857	10,536,000		10,536,000					10,107,000
Series A-2 [Member]
Preferred Units [Line Items]
Proceeds from Issuance of Convertible Preferred Units										$ 45,000,000
Investment options, exercise price (in usd per share)				$ 17.50				$ 15.24
Shares issued upon conversion (in shares)						1.1483		1.1483
Call right defined acquisition value				$ 100,000,000
Series A [Member]
Preferred Units [Line Items]
Investment options, exercise price (in usd per share)								$ 15.24
Shares issued upon conversion (in shares)						1.1483		1.1483
Distribution per unit					$ 0.4125
Series C [Member]
Preferred Units [Line Items]
Partners' Capital Account, Units						8,792,000		8,792,000					8,792,000
Investment options, exercise price (in usd per share)			$ 14
Class of warrant, number of securities called by warrants (in shares)			800,000
Class of warrant, exercise price of warrants (in usd per share)			$ 7.25
Warrant, exercisable period			7 years					7 years
Fair value of warrant unit (in usd per share)						$ 4.41		$ 4.41
Expected dividend rate								18.00%
Fair value assumptions, expected volatility rate								42.00%
Issuance of warrant								$ 4,500,000
Series C [Member]
Preferred Units [Line Items]
Investment options, exercise price (in usd per share)								$ 13.40
Shares issued upon conversion (in shares)			1			1.0448		1.0448
Series D [Member]
Preferred Units [Line Items]
Partners' Capital Account, Units						2,333,000		2,333,000					2,333,000
Shares issued upon conversion (in shares)														1
Class of warrant, number of securities called by warrants (in shares)														700,000
Class of warrant, exercise price of warrants (in usd per share)														$ 22
Units issued (in shares)														2,333,333
Shares issued, price per share (in usd per share)														$ 15
Closing fee percent														1.50%
Distribution per unit						$ 0.4125		$ 0.4125		$ 0.50		$ 0.4125
Preferred, units, outstanding (in shares)						2,333,333		2,333,333
Series D [Member]
Preferred Units [Line Items]
Shares issued upon conversion (in shares)						1.0035		1.0035
Class of warrant, exercise price of warrants (in usd per share)						$ 14.83		$ 14.83
High Point Infrastructure Partners, LLC [Member] | Series A [Member]
Preferred Units [Line Items]
Issuance of units					$ 15,000,000
Magnolia Infrastructure Partners, LLC [Member] | Issuance of Preferred Units [Member] | Series A-2 [Member]
Preferred Units [Line Items]
Partners' Capital Account, Units, Sold in Private Placement										2,571,430
ArcLight [Member] | Issuance of Preferred Units [Member] | Series C [Member]
Preferred Units [Line Items]
Partners' Capital Account, Units, Sold in Private Placement			8,571,429
Subsequent Event [Member]
Preferred Units [Line Items]
Distribution declared per common unit (in usd per share)		$ 0.4125
Subsequent Event [Member] | Series D [Member]
Preferred Units [Line Items]
Preferred, units, outstanding (in shares)											0
[1]	Declared and paid each quarter related to prior quarter.

Partners Capital (Narrative) (D

Partners Capital (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Class of Stock [Line Items]
General partner interest	1.30%
Limited partner interests	98.70%
Proceeds from General Partner	$ 42,270	$ 9,401
Additional notional General Partner units (shares)	272,811	135,813
Fair value inputs, assumed growth rate (percent)	1.00%
General Partner [Member]
Class of Stock [Line Items]
Contributions to maintain ownership percentage	$ 3,900
Proceeds from General Partner	$ 38,270	$ 1,901
Minimum [Member]
Class of Stock [Line Items]
Fair value input, option value (dollars per unit)	$ 0.88
Fair value inputs, discount rate (percent)	5.80%
Maximum [Member]
Class of Stock [Line Items]
Fair value input, option value (dollars per unit)	$ 3.39
Fair value inputs, discount rate (percent)	10.00%

Partners_ Capital Outstanding U

Partners’ Capital Outstanding Units (Details) shares in Thousands	9 Months Ended
	Sep. 30, 2017shares
Increase (Decrease) in Partners' Capital [Roll Forward]
Balances at December 31, 2016	680
Balances at December 31, 2016	51,351
Balances at September 30, 2017	953
Balances at September 30, 2017	52,740
General Partner [Member] | Long Term Incentive Plan [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Partners' Capital Account Increase	0
General Partner [Member] | General Partner Units [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Partners' Capital Account Increase	273
General Partner [Member] | Common Units [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Partners' Capital Account Increase	0
Limited Partner [Member] | Long Term Incentive Plan [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Partners' Capital Account Increase	460
Limited Partner [Member] | General Partner Units [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Partners' Capital Account Increase	0
Limited Partner [Member] | Common Units [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Partners' Capital Account Increase	929

Partners_ Capital Distributions

Partners’ Capital Distributions (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Class of Stock [Line Items]
General partner's distribution			$ 94,120	$ 103,771
Limited Partner [Member]
Class of Stock [Line Items]
General partner's distribution			93,144	96,134
General Partner [Member]
Class of Stock [Line Items]
General partner's distribution			976	7,637
Paid In-kind Unit [Member]
Class of Stock [Line Items]
General partner's distribution	$ 1,924	$ 3,100	6,838	7,571
Paid In-kind Unit [Member] | Series A [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	1,924	2,152	6,838	6,623
Paid In-kind Unit [Member] | Series C [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	0	948	0	948
Paid [Member] | Paid / Accrued [Member]
Class of Stock [Line Items]
General partner's distribution	28,357	28,799	88,851	82,782
Paid [Member] | Paid / Accrued [Member] | Limited Partner [Member]
Class of Stock [Line Items]
General partner's distribution	21,345	24,874	67,648	76,656
Paid [Member] | Paid / Accrued [Member] | General Partner [Member]
Class of Stock [Line Items]
General partner's distribution	277	174	645	2,375
Paid [Member] | Paid / Accrued [Member] | Series A [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	2,145	2,449	6,790	2,449
Paid [Member] | Paid / Accrued [Member] | Series C [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	3,627	1,302	10,880	1,302
Paid [Member] | Paid / Accrued [Member] | Series D [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	963	0	2,888	0
Accrued [Member] | General Partner [Member]
Class of Stock [Line Items]
General partner's distribution	287	174	763	2,375
Accrued [Member] | Paid / Accrued [Member]
Class of Stock [Line Items]
General partner's distribution	8,255	8,417	8,255	8,417
Accrued [Member] | Paid / Accrued [Member] | Series A [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	4,105	4,806	4,105	4,806
Accrued [Member] | Paid / Accrued [Member] | Series C [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	4,150	3,611	4,150	3,611
Accrued [Member] | Paid / Accrued [Member] | Series D [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	$ 0	$ 0	$ 0	$ 0

Net Loss per Limited Partner 85

Net Loss per Limited Partner Unit Net Loss per Limited Partner Unit (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net loss	$ 11,806	$ (5,488)	$ (42,266)	$ (35,414)
Less: Net income attributable to noncontrolling interests	621	1,241	3,386	2,192
Net income (loss) from continuing operations attributable to the Partnership	11,185	(6,729)	(45,652)	(37,606)
General partner's distribution			94,120	103,771
General partner’s share in undistributed loss	(210)	(375)	(1,729)	(1,334)
Net loss from continuing operations available to Limited Partners	2,853	(14,945)	(70,486)	(58,386)
Net loss from discontinued operations available to Limited Partners	44,696	(2,310)	42,185	7,532
Net loss available to Limited Partners	$ 47,549	$ (17,255)	$ (28,301)	$ (50,854)
Weighted average number of common units outstanding: basic and diluted (shares)	52,021	51,310	52,021	51,310
Limited Partners' net income (loss) from continuing operations per unit (in usd per unit)	$ 0.05	$ (0.29)	$ (1.35)	$ (1.14)
Limited Partners' net income (loss) from discontinued operations per unit (in usd per unit)	0.86	(0.05)	0.81	0.15
Limited Partners' net loss per common unit (in usd per share)	$ 0.91	$ (0.34)	$ (0.54)	$ (0.99)
Series A [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Distributions	$ 4,105	$ 4,806	$ 12,472	$ 13,879
Series C [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Distributions	4,150	3,611	11,403	5,860
Series D [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Distributions	0	0	1,925	0
General Partner [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
General partner's distribution			976	7,637
General Partner [Member] | Accrued [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
General partner's distribution	$ 287	$ 174	$ 763	$ 2,375

Long Term Incentive Plan (Narra

Long Term Incentive Plan (Narrative) (Details) - USD ($) $ in Thousands	Mar. 09, 2017	Nov. 19, 2015	Dec. 31, 2015	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity compensation expense						$ 6,067	$ 4,285
Parent [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity compensation expense				$ 800	$ 1,800	6,067	4,285
Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Additional number of common units authorized for issuance (shares)	312,716	6,000,000
Equity instruments other than options, vested in period, fair value						$ 9,400	$ 1,800
Long Term Incentive Plan [Member] | Phantom Share Units (PSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period			3 years
Granted (in shares)			200,000
Long Term Incentive Plan [Member] | Minimum [Member] | Phantom Share Units (PSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period						3 years
Long Term Incentive Plan [Member] | Maximum [Member] | Phantom Share Units (PSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period						4 years

Long-Term Incentive Plan - Phan

Long-Term Incentive Plan - Phantom Units (Details) - Phantom Share Units (PSUs) [Member]	9 Months Ended
	Sep. 30, 2017$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Outstanding at end beginning of period (in shares) | shares	1,558,835
Granted (in shares) | shares	2,000
Forfeited (in shares) | shares	(18,919)
Vested (in shares) | shares	(570,038)
Outstanding at end of period (in shares) | shares	971,878
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Weighted Average [Roll Forward]
Outstanding at beginning of period (in usd per share) | $ / shares	$ 6.98
Granted (in usd per share) | $ / shares	11.20
Forfeited (in usd per share) | $ / shares	13.49
Vested (in usd per share) | $ / shares	11.13
Outstanding at end of period (in usd per share) | $ / shares	$ 4.43

Related Party Transactions (Na

Related Party Transactions (Narrative) (Details)	3 Months Ended			9 Months Ended		12 Months Ended	45 Months Ended
	Sep. 30, 2017USD ($)quarter	Mar. 31, 2017USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2017USD ($)quarter	Sep. 30, 2016USD ($)	Dec. 31, 2016USD ($)	Sep. 30, 2017USD ($)quarter	Dec. 31, 2015USD ($)	Dec. 31, 2013USD ($)
Related Party Transaction [Line Items]
Contributions				$ 38,270,000	$ 1,901,000
Due from related parties	$ 5,062,000			5,062,000		$ 4,833,000	$ 5,062,000
Direct operating expenses	20,705,000		$ 17,571,000	56,819,000	53,872,000
Direct operating expenses	27,083,000		22,103,000	84,570,000	60,945,000
Blackwater [Member]
Related Party Transaction [Line Items]
Additional consideration									$ 5,000,000
Additional Blackwater acquisition consideration	$ 5,000,000			$ 5,000,000			$ 5,000,000
General Partner [Member]
Related Party Transaction [Line Items]
Maximum financial support		$ 25,000,000
Term of maximum financial support (Number of Quarters) | quarter	8			8			8
Financial support utilized							$ 25,000,000
Contributions		3,900,000
Direct operating expenses	$ 0		3,500,000	$ 4,000,000	7,500,000
Corporate overhead expenses to be absorbed by general partner		$ 9,600,000	0		5,000,000
Republic Midstream, LLC (“Republic”) [Member]
Related Party Transaction [Line Items]
Monthly fee				100,000
Revenue from related parties	400,000		200,000	1,000,000	600,000
Receivable balance from affiliate	1,500,000			1,500,000			$ 1,500,000
Affiliated Entity [Member]
Related Party Transaction [Line Items]
Management fees revenue				1,900,000
J P Energy Development L P [Member]
Related Party Transaction [Line Items]
Net receivable from JP Development								$ 7,900,000
Capstone Ventures, LLC [Member]
Related Party Transaction [Line Items]
Revenue from related parties	$ 200,000		200,000	700,000	500,000
Director [Member] | McCown Enterprises, LLC [Member]
Related Party Transaction [Line Items]
Revenue from related parties				$ 300,000	200,000
Ownership interest (percent)	50.00%			50.00%			50.00%
Other Current Liabilities [Member] | General Partner [Member]
Related Party Transaction [Line Items]
Related party transaction, due to related party	$ 4,700,000			$ 4,700,000		3,900,000	$ 4,700,000
Other Current Assets [Member]
Related Party Transaction [Line Items]
Due from related parties	$ 1,000,000			$ 1,000,000		2,200,000	$ 1,000,000
American Panther [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Ownership interest in subsidiary (percent)	60.00%			60.00%			60.00%
American Panther [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Direct operating expenses				$ 1,500,000		800,000
Direct operating expenses				$ 300,000		$ 400,000
Panther Asset Management LLC (Panther) [Member] | American Panther [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Noncontrolling interest ownership interest (percent)	40.00%			40.00%			40.00%
CIMA Energy Ltd [Member] | Vice President [Member]
Related Party Transaction [Line Items]
Revenue from related parties	$ 3,700,000		1,100,000	$ 6,200,000	2,700,000
Purchases from related party	$ 1,100,000		$ 1,200,000	$ 3,700,000	3,000,000
Crude Oil Pipelines And Storage Segment [Member] | Mid Continent Business [Member] | J P Energy Development L P [Member]
Related Party Transaction [Line Items]
Pipeline tariff fees					$ 400,000

Supplemental Cash Flow Inform89

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Limited Partners' Capital Account [Line Items]
Increase (decrease) in accrued property, plant and equipment purchases	$ (15,112)	$ 4,597
Issuance of common units for the Panther acquisition	12,532	0
Contributions	42,270	9,401
Issuance of Series C Units and Warrant in connection with the Emerald Transactions	0	120,000
Accrued distributions on convertible preferred units	8,255	8,417
Paid-in-kind distributions on convertible preferred units	6,838	7,571
Cancellation of escrow units	0	6,817
Accrued Cash Dividends Paid to Parent Company by Unconsolidated Affiliates	0	5,000
Limited Partner [Member]
Limited Partners' Capital Account [Line Items]
Contributions	$ 4,000	$ 7,500

Reportable Segments - Reconcili

Reportable Segments - Reconciliation of Gross Profit (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Segment Reporting Information [Line Items]
Segment gross margin	$ 63,746	$ 58,793	$ 186,145	$ 164,237
Direct operating expenses	20,705	17,571	56,819	53,872
Operating Income (Loss)	(20,616)	(9,724)	(70,647)	(38,610)
Derivative, Gain (Loss) on Derivative, Net	(597)	324	(33)	(1,929)
Corporate expenses	27,083	22,103	84,570	60,945
Depreciation, amortization and accretion	26,781	22,668	78,834	65,937
(Gain) loss on sale of assets, net	(4,061)	36	(4,064)	297
Interest expense	17,759	5,830	51,037	24,723
Other income	(34,085)	1	(32,248)	(245)
Other (income) expense, net	(139)	(1,129)	322	(1,773)
Income tax expense	731	401	2,611	1,839
(Income) loss from discontinued operations, net of tax	(44,696)	2,310	(42,185)	(7,532)
Less: Net income attributable to noncontrolling interests	621	1,241	3,386	2,192
Net income (loss) attributable to the Partnership	55,881	(9,039)	(3,467)	(30,074)
Gathering and Processing reporting segment [Member]
Segment Reporting Information [Line Items]
Segment gross margin	12,761	12,627	36,663	37,586
Direct operating expenses	8,655	7,856	24,766	25,344
Derivative, Gain (Loss) on Derivative, Net	(65)	149	(170)	(716)
Liquid Pipelines and Services [Member]
Segment Reporting Information [Line Items]
Segment gross margin	7,808	7,600	21,209	23,829
Direct operating expenses	2,438	2,617	7,137	8,186
Derivative, Gain (Loss) on Derivative, Net	(532)	177	137	(772)
Natural Gas Transportation Services [Member]
Segment Reporting Information [Line Items]
Segment gross margin	5,356	3,709	17,106	13,115
Direct operating expenses	2,240	1,324	5,403	4,515
Derivative, Gain (Loss) on Derivative, Net	0	0	0	0
Offshore Pipelines and Services [Member]
Segment Reporting Information [Line Items]
Segment gross margin	29,312	24,126	80,738	57,947
Direct operating expenses	3,940	2,898	10,010	7,954
Derivative, Gain (Loss) on Derivative, Net	0	(2)	0	(5)
Terminalling Services [Member]
Segment Reporting Information [Line Items]
Segment gross margin	8,509	10,731	30,429	31,760
Direct operating expenses	3,432	2,876	9,503	7,873
Derivative, Gain (Loss) on Derivative, Net	0	0	0	(436)
All Operating Segments, Excluding Terminalling Segment [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	$ 17,274	$ 14,695	$ 47,316	$ 45,999

Reportable Segments (Narrative)

Reportable Segments (Narrative) (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2017USD ($)segments	Sep. 30, 2016USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | segments			5
Direct operating expenses	$ 20,705	$ 17,571	$ 56,819	$ 53,872
Gathering and Processing reporting segment [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	8,655	7,856	24,766	25,344
Liquid Pipelines and Services [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	2,438	2,617	7,137	8,186
Natural Gas Transportation Services [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	2,240	1,324	5,403	4,515
Offshore Pipelines and Services [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	3,940	2,898	10,010	7,954
Terminalling Services [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	$ 3,432	$ 2,876	$ 9,503	$ 7,873

Reportable Segments (Details)

Reportable Segments (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Segment information
Revenue	$ 162,887	$ 159,579	$ 488,431	$ 415,082
Gain (loss) on commodity derivatives, net	(597)	324	(33)	(1,929)
Total revenue	162,290	159,903	488,398	413,153
Earnings in unconsolidated affiliates	16,827	10,468	49,781	29,513
Cost of Sales	112,398	107,249	342,886	270,712
Direct operating expenses	20,705	17,571	56,819	53,872
Corporate expenses	27,083	22,103	84,570	60,945
Depreciation, amortization and accretion	26,781	22,668	78,834	65,937
(Gain) loss on sale of assets, net	(4,061)	36	(4,064)	297
Total operating expenses	182,906	169,627	559,045	451,763
Interest expense	17,759	5,830	51,037	24,723
Other income (expense), net	34,085	(1)	32,248	245
Income (loss) from continuing operations before income taxes	12,537	(5,087)	(39,655)	(33,575)
Income tax expense	731	401	2,611	1,839
Loss from continuing operations	11,806	(5,488)	(42,266)	(35,414)
Income (loss) from discontinued operations, including net gain on disposition of $46.5 million (Note 4)	44,696	(2,310)	42,185	7,532
Loss from discontinued operations, net of tax	44,696	(2,310)	42,185	7,532
Net income (loss)	56,502	(7,798)	(81)	(27,882)
Less: Net income attributable to noncontrolling interests	621	1,241	3,386	2,192
Less: Net income attributable to noncontrolling interests	621	1,241	3,386	2,192
Net income (loss) attributable to the Partnership	55,881	(9,039)	(3,467)	(30,074)
Segment gross margin	63,746	58,793	186,145	164,237
Gathering and Processing reporting segment [Member]
Segment information
Revenue	37,287	31,650	111,001	85,655
Gain (loss) on commodity derivatives, net	(65)	149	(170)	(716)
Total revenue	37,222	31,799	110,831	84,939
Earnings in unconsolidated affiliates	0		0	0
Cost of Sales	24,492	18,477	74,261	47,344
Direct operating expenses	8,655	7,856	24,766	25,344
Segment gross margin	12,761	12,627	36,663	37,586
Liquid Pipelines and Services [Member]
Segment information
Revenue	87,022	87,898	253,590	221,866
Gain (loss) on commodity derivatives, net	(532)	177	137	(772)
Total revenue	86,490	88,075	253,727	221,094
Earnings in unconsolidated affiliates	1,317	650	3,886	1,658
Cost of Sales	80,510	80,372	236,896	199,111
Direct operating expenses	2,438	2,617	7,137	8,186
Segment gross margin	7,808	7,600	21,209	23,829
Natural Gas Transportation Services [Member]
Segment information
Revenue	11,131	10,709	34,966	28,383
Gain (loss) on commodity derivatives, net	0	0	0	0
Total revenue	11,131	10,709	34,966	28,383
Earnings in unconsolidated affiliates	0	0	0	0
Cost of Sales	5,692	6,994	17,630	15,245
Direct operating expenses	2,240	1,324	5,403	4,515
Segment gross margin	5,356	3,709	17,106	13,115
Offshore Pipelines and Services [Member]
Segment information
Revenue	14,360	14,879	41,330	32,526
Gain (loss) on commodity derivatives, net	0	(2)	0	(5)
Total revenue	14,360	14,877	41,330	32,521
Earnings in unconsolidated affiliates	15,510	9,819	45,895	27,855
Cost of Sales	558	570	6,487	2,429
Direct operating expenses	3,940	2,898	10,010	7,954
Segment gross margin	29,312	24,126	80,738	57,947
Terminalling Services [Member]
Segment information
Revenue	13,087	14,443	47,544	46,652
Gain (loss) on commodity derivatives, net	0	0	0	(436)
Total revenue	13,087	14,443	47,544	46,216
Earnings in unconsolidated affiliates	0	0	0	0
Cost of Sales	1,146	836	7,612	6,583
Direct operating expenses	3,432	2,876	9,503	7,873
Segment gross margin	$ 8,509	$ 10,731	$ 30,429	$ 31,760

Reportable Segments - Assets (D

Reportable Segments - Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Assets	$ 2,023,207	$ 2,349,321
Gathering and Processing reporting segment [Member]
Segment Reporting Information [Line Items]
Assets	416,498	530,889
Liquid Pipelines and Services [Member]
Segment Reporting Information [Line Items]
Assets	443,771	425,389
Offshore Pipelines and Services [Member]
Segment Reporting Information [Line Items]
Assets	544,895	400,193
Natural Gas Transportation Services [Member]
Segment Reporting Information [Line Items]
Assets	172,813	221,604
Terminalling Services [Member]
Segment Reporting Information [Line Items]
Assets	256,922	299,534
Other Segments [Member]
Segment Reporting Information [Line Items]
Assets	188,308	334,953
Discontinued Operations [Member]
Segment Reporting Information [Line Items]
Assets	$ 0	$ 136,759

Subsequent Events (Details)

Subsequent Events (Details) $ / shares in Units, MMBTU in Thousands		Nov. 06, 2017USD ($)MMBTU	Oct. 31, 2017USD ($)$ / sharesshares	Oct. 27, 2017USD ($)billion_cubic_feet_per_daymi	Oct. 26, 2017$ / shares	Oct. 02, 2017USD ($)shares	Sep. 30, 2017$ / sharesshares	Sep. 30, 2016$ / shares	Sep. 30, 2017$ / sharesshares	Sep. 30, 2016$ / shares	Dec. 31, 2016shares
Subsequent Event [Line Items]
Preferred, units, outstanding (in shares) | shares							52,740,000		52,740,000		51,351,000
Distribution declared per common unit (in usd per share) | $ / shares	[1]						$ 0.4125	$ 0.4125	$ 1.2375	$ 1.2975
Subsequent Event [Member]
Subsequent Event [Line Items]
Distribution declared per common unit (in usd per share) | $ / shares					$ 0.4125
Distribution made to limited partner, distributions declared, per unit, annualized basis (in usd per share) | $ / shares					$ 1.65
Estimated net debt to be repaid as part of acquisition		$ 32,500,000
Throughput capacity per day | MMBTU		546
Series D [Member]
Subsequent Event [Line Items]
Preferred, units, outstanding (in shares) | shares							2,333,333		2,333,333
Series D [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Preferred, units, outstanding (in shares) | shares						0
Payments for repurchase of convertible preferred stock						$ 37,000,000
American Midstream Emerald, LLC [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Equity interests acquired (percent)				17.00%
Total consideration upon acquisition				$ 30,000,000
Current ownership interest (percent)				66.67%
Transmission capacity (bcf per day) | billion_cubic_feet_per_day				1.2
Length of pipeline | mi				255
Southcross Energy Partners (SXE) [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Fair value of planned acquisition			$ 815,000,000
Estimated repayment of debt			$ 139,000,000
Partners capital account common units conversion ratio			0.160
Contribution agreement, common units to be exchanged in merger transaction			$ 185,697,148
Contribution agreement, per common unit denominator (usd per share) | $ / shares			$ 13.69
Trans-Union Pipeline, L.P. (“Trans-Union”) [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Equity interests acquired (percent)		100.00%
Total consideration upon acquisition		$ 48,000,000
Cash payment made to acquire business		$ 15,500,000
General Partner Class D Units [Member] | Southcross Energy Partners (SXE) [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Contribution agreement, common units to be exchanged in merger transaction, (shares) | shares			3,000
Preferred Units [Member] | Southcross Energy Partners (SXE) [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Contribution agreement, common units to be exchanged in merger transaction, (shares) | shares			4,500,000
Common Units [Member] | Southcross Energy Partners (SXE) [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Contribution agreement, common units to be exchanged in merger transaction, (shares) | shares			4,500,000
[1]	Declared and paid each quarter related to prior quarter.