Third Coast Midstream (AMID) 10-Q 15 May 17 2017 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2017	May 05, 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	Mar. 31, 2017
Amendment Flag	false
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding (in shares)		51,730,964
Series A [Member]
Document Information [Line Items]
Entity Common Stock, Shares Outstanding (in shares)		10,266,642
Series C [Member]
Document Information [Line Items]
Entity Common Stock, Shares Outstanding (in shares)		8,792,205
Series D [Member]
Document Information [Line Items]
Entity Common Stock, Shares Outstanding (in shares)		2,333,333

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Current assets
Cash and cash equivalents	$ 16,919	$ 5,666
Restricted cash	22,294	0
Accounts receivable, net of allowance for doubtful accounts of $2,480 and $1,871, respectively	24,770	27,769
Unbilled revenue	57,865	55,646
Inventory	9,614	6,776
Other current assets	28,012	27,667
Total current assets	159,474	123,524
Risk management assets - long term	9,624	10,664
Property, plant and equipment, net	1,142,302	1,145,003
Goodwill	217,498	217,498
Restricted cash- long term	5,037	323,564
Intangible assets, net	218,015	225,283
Investment in unconsolidated affiliates	284,896	291,988
Other assets, net	9,397	11,797
Total assets	2,046,243	2,349,321
Current liabilities
Accounts payable	37,833	45,278
Accrued gas purchases	10,294	7,891
Accrued expenses and other current liabilities	80,887	81,284
Current portion of debt	3,223	5,485
Total current liabilities	132,237	139,938
Asset retirement obligations	44,809	44,363
Other liabilities	2,250	2,030
Revolving credit agreement	644,842	888,250
Deferred tax liability	8,883	8,205
Total liabilities	1,181,116	1,430,074
Commitments and contingencies
Convertible preferred units	336,271	334,090
Equity and partners’ capital
General Partner interests (688 thousand and 680 thousand units issued and outstanding as of March 31, 2017 and December 31, 2016, respectively)	(47,055)	(47,645)
Accumulated other comprehensive income (loss)	(22)	(40)
Total partners’ capital	511,386	568,402
Noncontrolling interests	17,470	16,755
Total equity and partners’ capital	528,856	585,157
Total liabilities, equity and partners’ capital	2,046,243	2,349,321
Limited Partner Common Units [Member]
Equity and partners’ capital
Limited Partner interests (51,631 thousand and 51,351 thousand units issued and outstanding as of March 31, 2017 and December 31, 2016, respectively)	558,463	616,087
Senior Notes [Member] | 3.77% Senior Notes [Member]
Current liabilities
Senior notes	55,895	55,979
Senior Notes [Member] | 8.50% Senior Notes [Member]
Current liabilities
Senior notes	$ 292,200	$ 291,309

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) shares in Thousands, $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Allowance for doubtful accounts receivable	$ 2,480	$ 1,871
General partner interest units, outstanding (in shares)	688	680
Preferred, units, outstanding (in shares)	51,631	51,351
Partnership Interest [Member]
General partner interest, units issued (in shares)	688	680
General partner interest units, outstanding (in shares)	688	680
Partnership Interest [Member] | Limited Partner Common Units [Member]
Preferred, units, issued (in shares)	51,631	51,351
Preferred, units, outstanding (in shares)	51,631	51,351

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands		3 Months Ended
		Mar. 31, 2017	Mar. 31, 2016
Depreciation, amortization and accretion expense		$ 29,351	$ 25,252
Revenue:
Commodity sales		158,501	107,570
Services		41,388	36,044
Gain (loss) on commodity derivatives, net		(257)	(238)
Total revenue		199,632	143,376
Operating expenses:
Costs of sales		132,785	73,938
Direct operating expenses		30,088	30,575
Corporate expenses		32,844	21,101
Depreciation, amortization and accretion expense		29,351	25,041
(Gain) loss on sale of assets, net		(228)	1,122
Total operating expenses		224,840	151,777
Operating loss		(25,208)	(8,401)
Other income (expense), net
Interest expense		(17,966)	(8,302)
Other income (expense)		14	31
Earnings in unconsolidated affiliates		15,402	7,343
Loss from continuing operations before taxes		(27,758)	(9,329)
Income tax expense		(1,123)	(735)
Loss from continuing operations		(28,881)	(10,064)
Loss from discontinued operations, net of tax		0	(539)
Net loss		(28,881)	(10,603)
Less: Net income (loss) attributable to noncontrolling interests		1,303	(3)
Net loss attributable to the Partnership		$ (30,184)	$ (10,600)
Distribution declared per common unit (in usd per share)	[1]	$ 0.4125	$ 0.4725
Limited Partners’ net loss per common unit, basic and diluted:
Loss from continuing operations (in usd per share)		(0.75)	(0.32)
Loss from discontinued operations (in usd per share)		0	(0.01)
Net loss (in usd per share)		$ (0.75)	$ (0.33)
Weighted average number of common units outstanding:
Weighted average number of common units outstanding: basic and diluted (shares)		51,451	50,925
General Partner [Member]
Other income (expense), net
Net loss		$ (420)	$ (97)
General Partner’s interest in net loss		(420)	(97)
Limited Partner [Member]
Other income (expense), net
Net loss		(29,764)	(10,503)
Limited Partners’ interest in net loss		$ (29,764)	$ (10,503)
[1]	udited, in thousands, except per unit amounts) Three months ended March 31, 2017 2016Revenue: Commodity sales$158,501 $107,570Services41,388 36,044 Gain (loss) on commodity derivatives, net(257) (238)Total revenue199,632143,376Operating expenses: Costs of sales132,785 73,938Direct operating expenses30,088 30,575Corporate expenses32,844 21,101Depreciation, amortization and accretion expense29,351 25,041(Gain) loss on sale of assets, net(228) 1,122Total operating expenses224,840151,777Operating loss(25,208)(8,401)Other income (expense), net Interest expense(17,966) (8,302)Other income (expense)14 31Earnings in unconsolidated affiliates15,402 7,343Loss from continuing operations before taxes(27,758)(9,329)Income tax expense(1,123) (735)Loss from continuing operations(28,881)(10,064)Loss from discontinued operations, net of tax— (539)Net loss(28,881)(10,603)Less: Net income (loss) attributable to noncontrolling interests1,303 (3)Net loss attributable to the Partnership$(30,184)$(10,600) General Partner’s interest in net loss$(420) $(97)Limited Partners’ interest in net loss$(29,764) $(10,503) Distribution declared per common unit (1)$0.4125 $0.4725Limited Partners’ net loss per common unit (See Note 14): Basic and diluted: Loss from continuing operations$(0.75) $(0.32)Loss from discontinued operations— (0.01)Net loss$(0.75)$(0.33)Weighted average number of common units outstanding:Basic and diluted51,451 50,925(1) Declared and paid

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Comprehensive Income (Loss) (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Statement of Comprehensive Income [Abstract]
Net loss	$ (28,881)	$ (10,603)
Unrealized gain (loss) related to postretirement benefit plan	18	14
Comprehensive loss	(28,863)	(10,589)
Less: Comprehensive income (loss) attributable to noncontrolling interests	1,303	(3)
Comprehensive loss attributable to the Partnership	$ (30,166)	$ (10,586)

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Changes in Partners' Capital (Unaudited) - USD ($) $ in Thousands	Total	Parent [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interest [Member]	Series B [Member]	General Partner [Member]	Limited Partner [Member]
Partners' Capital at Dec. 31, 2015		$ 739,930	$ 40	$ 12,111	$ 33,593	$ (47,091)	$ 753,388
Increase (Decrease) in Temporary Equity [Roll Forward]
Net income (loss)	$ (10,603)	(10,600)		(3)		(97)	(10,503)
Issuance of common units, net of offering costs		(104)					(104)
Cancellation of escrow units	(6,817)	(6,817)					(6,817)
Conversion of Series B units		0			(33,593)		33,593
Contributions	2,500	2,592				92	2,500
Distributions		(33,499)				(2,087)	(31,412)
Contributions from noncontrolling interest owners				85
LTIP vesting		0				(2,041)	2,041
Tax netting repurchase	150	(150)					(150)
Equity compensation expense		1,643				1,084	559
Other comprehensive income		14	14
Addition of Mesquite NCI				(210)
Partners' Capital at Mar. 31, 2016		693,009	54	12,403	0	(50,140)	743,095
Partners' Capital at Dec. 31, 2016	568,402	568,402	(40)		0	(47,645)	616,087
Increase (Decrease) in Temporary Equity [Roll Forward]
Net income (loss)	(28,881)	(30,184)		1,303		(420)	(29,764)
Issuance of common units, net of offering costs		(72)
Cancellation of escrow units	0
Contributions	4,000	4,123		0		123	4,000
Distributions		(33,967)				(282)	(33,685)
Contributions from noncontrolling interest owners				280
Distributions to noncontrolling interests owners				(868)
LTIP vesting						(2,135)	2,135
Tax netting repurchase	971	(971)					(971)
Equity compensation expense		4,037		0		3,304	733
Other comprehensive income		18	18
Partners' Capital at Mar. 31, 2017	$ 511,386	$ 511,386	$ (22)	$ 17,470	$ 0	$ (47,055)	$ 558,463

Condensed Consolidated Stateme7

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Cash flows from operating activities
Net loss	$ (28,881)	$ (10,603)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, amortization and accretion expense	29,351	25,252
Amortization of deferred financing costs	1,253	702
Amortization of weather derivative premium	257	219
Unrealized loss on derivatives contracts, net	1,273	1,382
Non-cash compensation expense	4,037	1,643
(Gain) loss on sale of assets, net	(228)	1,008
Corporate overhead support	4,000	2,500
Other non-cash items	1,965	41
Earnings in unconsolidated affiliates	(15,402)	(7,343)
Distributions from unconsolidated affiliates	15,402	7,343
Deferred tax expense	678	294
Allowance for bad debts	830	(6)
Changes in operating assets and liabilities, net of effects of assets acquired and liabilities assumed:
Accounts receivable	1,285	340
Inventory	(2,626)	(5,592)
Unbilled revenue	(1,019)	18,833
Other current assets	3,114	6,720
Other assets, net	168	226
Restricted cash	(3,135)	0
Accounts payable	(9,716)	(10,909)
Accrued gas purchases	2,403	(749)
Accrued expenses and other current liabilities	994	(1,359)
Asset retirement obligations	(41)	0
Other liabilities	(195)	(674)
Net cash provided by operating activities	5,767	29,268
Cash flows from investing activities
Additions to plant, property and equipment	(20,221)	(26,319)
Proceeds from disposals of plant, property and equipment	51	11,126
Insurance proceeds from involuntary conversion of property, plant and equipment	150	0
Investment in unconsolidated affiliates	0	(3,546)
Distributions from unconsolidated affiliates, return of capital	7,092	6,172
Restricted cash	299,313	0
Net cash provided by (used in) investing activities	286,385	(12,567)
Cash flows from financing activities
Proceeds from issuance of common units to public, net of offering costs	(72)	(104)
Contributions	123	92
Distributions	(32,198)	(29,028)
Contribution from noncontrolling interest owners	280	85
Distributions to noncontrolling interests owners	(868)	0
LTIP tax netting unit repurchase	(971)	(150)
Payment of financing costs	(1,402)	(323)
Payments on other debt	(2,363)	(844)
Borrowings on other debt	0	867
Payments on credit agreement	(325,908)	(59,450)
Borrowings on credit agreement	82,500	71,750
Other	(20)	(44)
Net cash used in financing activities	(280,899)	(17,149)
Net increase (decrease) in cash and cash equivalents	11,253	(448)
Cash and cash equivalents
Beginning of period	5,666	1,987
End of period	$ 16,919	$ 1,539

Organization, Basis of Presenta

Organization, Basis of Presentation and Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization, Basis of Presentation and Summary of Significant Accounting Policies	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% 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. Merger with JPE 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 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 both we and JPE were controlled by ArcLight affiliates, the acquisition represents 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 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. 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 six reportable segments, (1) gas gathering and processing services, (2) liquids pipelines and services, (3) natural gas transportation services, (4) offshore pipelines and services, (5) terminalling services and (6) propane marketing 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 distributing and selling propane and refined products. Most of our cash flow is generated from fee-based and fixed-margin compensation 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 transmission and terminal assets are in key demand markets in Oklahoma, Alabama, Arkansas, Louisiana, Mississippi and Tennessee and in the Port of New Orleans in Louisiana and the Port of Brunswick in Georgia. Our propane marketing services include commercial and retail operations across 46 of the lower 48 states. Basis of presentation The unaudited financial information included in this Form 10-Q has been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2016, except that the consolidated financial statements have been retrospectively adjusted to reflect the consolidation of JPE, as discussed above. The results of operations for the three months ended March 31, 2017 is 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 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 will be 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 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, contracted arrangements and management restrictions. Such amounts are included in Restricted cash in our 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. As of March 31, 2017 and December 31, 2016 , we recorded allowances for doubtful accounts of $2.5 million and $1.9 million , respectively. Investment 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. 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 consolidated statements of operations. New Accounting Pronouncements Accounting Standards Issued Not Yet Adopted In May 2014, the FASB issued 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. In March 2016, the FASB issued ASU No. 2016-08, Revenue from Contracts with Customers (Topic 606): Principal Versus Agent Considerations, as further clarification on principal versus agent considerations. In April 2016, the FASB issued 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. In May 2016, the FASB issued 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 that these updates will have on our consolidated financial statements and related disclosures. We have engaged a third-party consultant to assist with our review and are still in the process of evaluating the method of adoption for transitioning to the new standard. In February 2016, the FASB issued ASU No. 2016-02 (Topic 842) " Leases " which supersedes the lease recognition requirements in Accounting Standards Codification 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. Based upon our evaluation to date, we anticipate that the adoption of ASU 2016-02 will have a material effect 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 have not yet determined the timing or manner in which we will implement the updated guidance. 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. Early adoption is permitted, but only if all aspects are adopted in the same period. We are currently evaluating the impact this update will have on our consolidated statements of cash flows and related disclosures. 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 are currently evaluating the impact that this update will have on our consolidated statement of cash flows and related disclosures. 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 a “set” (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. The adoption of ASU 2017-01 is not expected to have a material impact on our consolidated financial statements and related disclosures associated with acquisitions subsequent to the effective date. 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 are currently evaluating the impact this update will have on our consolidated financial statements and related disclosures.

Acquisitions

Acquisitions	3 Months Ended
	Mar. 31, 2017
Business Combinations [Abstract]
Acquisitions	Acquisitions JP Energy Partners LP On March 8, 2017, we completed the merger of JPE, an 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 represents a transaction among entities under common control and will be accounted for as a common control transaction. Although we are the legal acquirer, JPE is considered to be the acquirer for accounting purposes as ArcLight obtained control of JPE prior to obtaining control of the Partnership on April 15, 2013. As a result, JPE will record the acquisition of the Partnership at ArcLight’s historical cost basis. JPE owns, operates and develops a diversified portfolio of midstream energy assets with three business segments (i) crude oil pipelines and storage, (ii) refined products terminals and storage and (iii) NGL distribution and sales, which together provide midstream infrastructure solutions for the growing supply of crude oil, refined products and NGLs, in the United States.

Inventory (Notes)

Inventory (Notes)	3 Months Ended
	Mar. 31, 2017
Inventory Disclosure [Abstract]
Inventory	Inventory Inventory consists of the following as of March 31, 2017 and December 31, 2016 (in thousands): March 31, 2017 December 31, 2016 Crude oil $ 3,969 $ 1,216 NGLs 3,505 3,482 Refined products 439 291 Materials, supplies and equipment 1,701 1,787 Total inventory $ 9,614 $ 6,776

Other Current Assets

Other Current Assets	3 Months Ended
	Mar. 31, 2017
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Other Current Assets	Other Current Assets Other current assets consist of the following (in thousands): March 31, 2017 December 31, 2016 Prepaid insurance $ 7,729 $ 9,702 Insurance receivables 7,574 2,895 Due from related parties 7,083 4,805 Other receivables 3,928 2,998 Risk management assets 534 964 Other assets 1,164 6,303 Total $ 28,012 $ 27,667

Risk Management Activities

Risk Management Activities	3 Months Ended
	Mar. 31, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
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 Our normal business activities expose us to risks associated with changes in the market price of crude oil and natural gas, among other commodities. Management believes it is prudent to limit our exposure to these risks, which include our (i) propane purchases, (ii) pre-existing or anticipated physical crude oil and refined product sales and (iii) certain crude oil held in inventory. To meet this objective, we use 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. While these contracts are considered derivative financial instruments under ASC 815, they are not recorded at fair value, but on an accrual basis of accounting. 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 and 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 volume purchases (sales) of our outstanding commodity-related derivatives, excluding those contracts that qualified for the NPNS exception as of March 31, 2017 and December 31, 2016, none of which were designated as hedges for accounting purposes. March 31, 2017 December 31, 2016 Commodity Swaps Volume Maturity Volume Maturity Propane Fixed Price (Gallons) 7,767,296 April 30,2017 - December 31, 2019 4,364,880 January 31, 2017 - November 30, 2018 Crude Oil Fixed Price (Barrels) 61,000 May 31, 2017 - June 30, 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, 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 March 31, 2017 , our outstanding interest rate swap contracts consist of the following (in thousands): Notional Amount Term Fair Value $100,000 April 1, 2017 through December 29, 2017 $101 $100,000 December 29, 2017 through January 29, 2019 $287 $200,000 April 1, 2017 through September 3, 2019 $2,092 $100,000 January 1, 2018 through December 31, 2021 $2,847 $150,000 January 1, 2018 through December 31, 2022 $4,732 $10,059 The fair value of our interest rate swaps was estimated using a valuation methodology based upon forward interest rate 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 2016, we entered into a weather derivative to mitigate the impact of potential unfavorable weather on our operations under which we could receive payments totaling up to $30.0 million in the event that a hurricane of certain strength pass through the areas identified in the derivative agreement. The weather derivatives, which are accounted for using the intrinsic value method, were entered into with a single counterparty and we were not required to post collateral. We paid no premiums during the three months ended March 31, 2017 and 2016 , respectively. Premiums are amortized to Direct operating expenses on a straight-line basis over the 1 year term of the contract. Unamortized amounts associated with the weather derivatives were approximately $0.2 million and $0.4 million as of March 31, 2017 and December 31, 2016 , respectively, and are included in Other current assets on the consolidated balance sheets. The following table summarizes the fair values of our derivative contracts (before netting adjustments) included in the condensed consolidated balance sheets as of March 31, 2017 and December 31, 2016 (in thousands): Asset Derivatives Liability Derivatives Type Balance Sheet Classification March 31, December 31, 2016 March 31, December 31, 2016 Commodity swaps Other current assets $ 200 $ 607 $ — $ — Commodity swaps Accrued expenses and other current liabilities — — (316 ) (1 ) Commodity swaps Risk management assets - long term 3 37 — — Commodity swaps Other liabilities — — (201 ) (1 ) Interest rate swaps Other current assets 337 — — — Interest rate swaps Accrued expenses and other current liabilities — — — (252 ) Interest rate swaps Risk management assets- long term 9,722 10,628 — — Weather derivatives Other current assets $ 172 $ 429 $ — $ — 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 as of March 31, 2017 and December 31, 2016 that are subject to enforceable master netting arrangements (in thousands): Gross Risk Management Position Netting Adjustments Net Risk Management Position presented in the balance sheet Balance Sheet Classification March 31, December 31, 2016 March 31, December 31, 2016 March 31, December 31, 2016 Other current assets $ 709 $ 1,036 $ (175 ) $ (72 ) $ 534 $ 964 Risk management assets- long term 9,725 10,665 (101 ) (1 ) 9,624 10,664 Total assets $ 10,434 $ 11,701 $ (276 ) $ (73 ) $ 10,158 $ 11,628 Accrued expenses and other liabilities $ (316 ) $ (253 ) $ 175 $ 72 $ (141 ) $ (181 ) Other liabilities (201 ) (1 ) 101 1 (100 ) — Total liabilities $ (517 ) $ (254 ) $ 276 $ 73 $ (241 ) $ (181 ) For the three months ended March 31, 2017 and 2016 , respectively, 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): Realized Unrealized 2017 Gains (losses) on commodity derivatives, net $ 699 $ (956 ) Interest expense (65 ) (317 ) Direct operating expenses (257 ) — Total $ 377 $ (1,273 ) 2016 Gains (losses) on commodity derivatives, net $ (388 ) $ 150 Interest expense — (1,532 ) Direct operating expenses (219 ) — Total $ (607 ) $ (1,382 )

Property, Plant and Equipment,

Property, Plant and Equipment, Net	3 Months Ended
	Mar. 31, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, Net	Property, Plant and Equipment, Net Property, plant and equipment, net, consists of the following (in thousands): Useful Life (in years) March 31, December 31, Land N/A $ 21,390 $ 21,811 Construction in progress N/A 117,288 131,449 Buildings and improvements 4 to 40 24,407 24,323 Transportation equipment 5 to 15 45,519 44,060 Processing and treating plants 8 to 40 139,553 137,014 Pipelines, compressors and right-of-way 3 to 40 776,867 754,911 Storage 3 to 40 210,685 210,579 Equipment 3 to 31 107,715 104,235 Total property, plant and equipment 1,443,424 1,428,382 Accumulated depreciation (301,122 ) (283,379 ) Property, plant and equipment, net $ 1,142,302 $ 1,145,003 At March 31, 2017 and December 31, 2016 , gross property, plant and equipment included $305.1 million and $291.1 million , respectively, related to our FERC regulated interstate and intrastate assets. Depreciation expense totaled $21.6 million and $19.7 million for the three months ended March 31, 2017 and 2016 , respectively. Capitalized interest was $1.0 million and $0.5 million for the three months ended March 31, 2017 and 2016 , respectively.

Goodwill and Intangible Assets,

Goodwill and Intangible Assets, Net	3 Months Ended
	Mar. 31, 2017
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets, Net	Goodwill and Intangible Assets, Net Goodwill as of March 31, 2017 and December 31, 2016 consisted of the following (in thousands): March 31, December 31, Liquids Pipelines and Services $ 124,710 $ 124,710 Terminalling Services 77,425 77,425 Propane Marketing Services 15,363 15,363 $ 217,498 $ 217,498 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 30 years . Intangible assets, net, consist of the following (in thousands): March 31, 2017 Gross carrying amount Accumulated amortization Net carrying amount Customer relationships $ 133,503 $ (35,806 ) $ 97,697 Customer contracts 95,594 (35,634 ) 59,960 Dedicated acreage 53,350 (4,882 ) 48,468 Collaborative arrangements 11,884 (778 ) 11,106 Noncompete agreements 3,423 (3,175 ) 248 Other 751 (215 ) 536 Total $ 298,505 $ (80,490 ) $ 218,015 December 31, 2016 Gross carrying amount Accumulated amortization Net carrying amount Customer relationships $ 133,503 $ (31,471 ) $ 102,032 Customer contracts 95,594 (33,414 ) 62,180 Dedicated acreage 53,350 (4,439 ) 48,911 Collaborative arrangements 11,884 (601 ) 11,283 Noncompete agreements 3,423 (3,086 ) 337 Other 751 (211 ) 540 Total $ 298,505 $ (73,222 ) $ 225,283 Amortization expense related to our intangible assets totaled $7.3 million and $5.2 million for the three months ended March 31, 2017 and 2016 , respectively.

Investment in unconsolidated af

Investment in unconsolidated affiliates	3 Months Ended
	Mar. 31, 2017
Equity Method Investments and Joint Ventures [Abstract]
Investment in unconsolidated affiliates	Investment in unconsolidated affiliates The following table presents the activity in our investments in unconsolidated affiliates (in thousands): Delta House (1) Emerald Transactions FPS OGL Destin Tri-States Okeanos Wilprise MPOG Total Ownership % at March 31, 2017 20.1 % 20.1 % 49.7 % 16.7 % 66.7 % 25.3 % 66.7 % Balances at December 31, 2016 $ 64,483 $ 25,450 $ 110,882 $ 55,022 $ 27,059 $ 4,944 $ 4,148 $ 291,988 Earnings in unconsolidated affiliates 7,088 3,636 2,126 899 1,572 188 (107 ) 15,402 Distributions (6,986 ) (3,555 ) (6,258 ) (1,100 ) (3,667 ) (228 ) (700 ) (22,494 ) Balances at March 31, 2017 $ 64,585 $ 25,531 $ 106,750 $ 54,821 $ 24,964 $ 4,904 $ 3,341 $ 284,896 (1) Represents direct and indirect ownership interests in Class A Units. The following tables present the summarized combined financial information for our equity investments (amounts represent 100% of investee financial information): Balance Sheets: March 31, 2017 December 31, 2016 Current assets $ 87,406 $ 120,600 Non-current assets 1,353,629 1,387,675 Current liabilities 62,231 64,099 Non-current liabilities $ 584,742 $ 623,650 Three months ended March 31, Statements of Operations: 2017 2016 Revenue $ 98,439 $ 65,542 Cost of sales and operating expenses 18,300 5,392 Gross profit 80,139 60,150 Income from continuing operations 58,595 55,548 Net income $ 58,595 $ 55,548 The unconsolidated affiliates were determined to be variable interest entities due to disproportionate economic interests and decision making rights. In each case, we lack the power to direct the activities that most significantly impact the unconsolidated affiliate’s economic performance. 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 sheet at March 31, 2017 . In each case, we are not obligated to absorb losses greater than our proportional ownership percentages indicated above. Our right to receive residual returns is not limited to any amount less than the ownership percentages indicated above.

Accrued Expenses and Other Curr

Accrued Expenses and Other Current Liabilities	3 Months Ended
	Mar. 31, 2017
Other Liabilities Disclosure [Abstract]
Accrued Expenses and Other Current Liabilities	Accrued Expenses and Other Current Liabilities Accrued expenses and other current liabilities consists of the following (in thousands): March 31, 2017 December 31, 2016 Capital expenditures $ 11,302 $ 14,499 Accrued interest 8,526 5,743 Convertible preferred unit distributions 6,707 7,103 Employee compensation 7,881 10,804 Current portion of asset retirement obligation 6,499 6,499 Legal accrual 5,150 — Additional Blackwater acquisition consideration 5,000 5,000 Transaction costs 4,539 3,000 Royalties payable 3,597 3,926 Escrow settlement 3,135 — Customer deposits 2,083 3,080 Taxes payable 1,809 1,066 Due to related parties 1,523 4,072 Gas imbalances payable 1,454 1,098 Deferred financing costs — 2,743 Recoverable gas costs 393 1,126 Other 11,289 11,525 $ 80,887 $ 81,284

Asset Retirement Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	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 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 16 - Commitments and Contingencies . The following table presents activity in our asset retirement obligations for the three months ended March 31, 2017 (in thousands): Non-current balance $ 44,363 Current balance 6,499 Balances at December 31, 2016 $ 50,862 Expenditures (41 ) Accretion expense 487 Balances at March 31, 2017 $ 51,308 Less: current portion 6,499 Noncurrent asset retirement obligation $ 44,809 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 condensed consolidated balance sheets as of March 31, 2017 and December 31, 2016 .

Debt Obligations

Debt Obligations	3 Months Ended
	Mar. 31, 2017
Debt Disclosure [Abstract]
Debt Obligations	Debt Obligations Our outstanding debt consists of the following (in thousands): March 31, 2017 December 31, 2016 Revolving credit facility $ 644,842 $ 888,250 8.5% Senior Notes, due 2021 300,000 300,000 3.77% Senior Notes, due 2031 (Non-Recourse) 60,000 60,000 Other debt 1,546 3,809 Total debt obligations 1,006,388 1,252,059 Unamortized debt issuance costs (1) (10,228 ) (11,036 ) Total debt 996,160 1,241,023 Less: Current portion, including unamortized debt issuance costs (3,223 ) (5,485 ) Long term debt $ 992,937 $ 1,235,538 (1) Unamortized deferred financing costs related to the Credit Agreement are included in our condensed consolidated balance sheets in Other assets, net. Credit Agreement On March 8, 2017, we and our operating company, American Midstream, LLC, along with other of our subsidiaries entered into a 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 the 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. The Second Amended and Restated 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. In addition to the financial covenants described above, the agreement also contains customary representations and warranties (including those relating to organization and authorization, compliance with laws, absence of defaults, material agreements and litigation) and customary events of default (including those relating to monetary defaults, covenant defaults, cross defaults and bankruptcy events). As of March 31, 2017 , we had approximately $644.8 million of borrowings and $25.9 million of letters of credit outstanding under the Credit Agreement resulting in $670.7 million of available borrowing capacity. As of March 31, 2017 , our consolidated total leverage ratio was 4.64 and our interest coverage ratio was 6.19 , 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 three months ended March 31, 2017 and 2016 , the weighted average interest rate on borrowings under our Credit Agreement and the JPE revolver was approximately 4.44% and 4.07% , respectively. 8.50% Senior Unsecured Notes On December 28, 2016, we and American Midstream Finance Corporation, our wholly-owned subsidiary (the “Co-Issuer” and together with the Partnership, the “Issuers”), completed the issuance and sale of the 8.50% Senior Notes. The 8.50% Senior Notes are jointly and severally guaranteed by our existing direct and indirect wholly owned subsidiaries (other than the Co-Issuer) and certain of our future subsidiaries (the “Guarantors”). 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 condensed consolidated balance sheet as of December 31, 2016 . We also incurred $2.7 million of direct issuance costs resulting in net proceeds related to the 8.50% Senior Notes of $291.3 million . Upon the closing of the JPE Acquisition and the satisfaction of other related conditions the restricted cash was released from escrow on March 8, 2017 and used to repay and terminate JPE’s revolving credit facility and reduce borrowings under the Partnership’s Amended and Restated Credit Agreement then in effect. As of March 31, 2017 , the fair value of the 8.50% Senior Notes was $305.6 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 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. The Note Purchase Agreement includes customary representations and warranties, affirmative and negative covenants (including financial covenants), and events of default that are customary for a transaction of this type. Many of these provisions apply not only to Midla Financing and the Note Guarantors, but also to American Midstream Midla Financing Holdings, LLC (“Midla Holdings”), a wholly owned subsidiary of the Partnership and the sole member of Midla Financing. Among other things, 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 3.77% Senior 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. As of March 31, 2017 , the fair value of the 3.77% Senior Notes was $54.6 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)	3 Months Ended
	Mar. 31, 2017
Partners' Capital [Abstract]
Convertible Preferred Units	Convertible Preferred Units Our convertible preferred units consist of the following (in thousands): Series A Series C Series D Units $ Units $ Units $ December 31, 2016 10,107 $ 181,386 8,792 $ 118,229 2,333 $ 34,475 Paid in kind unit distributions 159 2,181 — — — — March 31, 2017 10,266 $ 183,567 8,792 $ 118,229 2,333 $ 34,475 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, although quarterly distribution on our Series D Units will only be paid in cash. 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 March 31, 2017 , the conversion price is $15.87 and the conversion ratio is 1 to 1.1027 . 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 March 31, 2017 , the conversion price is $15.87 and the conversion ratio is 1 to 1.1027 . Third Amendment to Partnership Agreement The Partnership also 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. 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 March 31, 2017 , the conversion price is $13.95 and the conversion ratio is 1 to 1.0036 . 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 . 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, 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. 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 June 30, 2017. As of the date of issuance, the conversion rate for each Series D Unit was one -to-one (the “Conversion Rate”). As of March 31, 2017 , the conversion price is $15.00 and the conversion ratio is 1 to 1.

Partners Capital

Partners Capital	3 Months Ended
	Mar. 31, 2017
Equity [Abstract]
Partners’ Capital and Convertible Preferred Units	Partners’ Capital Outstanding Units The following table presents unit activity (in thousands): General Limited Partner Interest Balances at December 31, 2016 680 51,351 LTIP vesting — 259 Issuance of common units — 21 Issuance of GP units 8 — Balances at March 31, 2017 688 51,631 Our capital accounts are comprised of approximately 0.9% notional General Partner interests and 99.1% limited partner interests as of March 31, 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. General Partner Units In order to maintain its ownership percentage, we received proceeds of $0.1 million from our General Partner as consideration for the issuance of 8,665 additional notional General Partner units for the three months ended March 31, 2017 . For the three months ended March 31, 2016 , we received proceeds of $0.1 million for the issuance of 6,225 additional notional General Partner units. Distributions We made the following distributions (in thousands): Three months ended March 31, 2017 2016 Series A Units Cash Paid $ 2,527 $ — Accrued 4,296 4,471 Paid-in-kind units 2,733 4,380 Series C Units Cash Paid 3,627 — Accrued 3,627 — Series D Units Cash Paid 962 — Accrued 962 — Limited Partner Units Cash Paid 24,915 27,000 General Partner Units Cash Paid 167 2,028 Summary Cash Paid 32,198 29,028 Accrued 8,885 4,471 Paid-in-kind units 2,733 4,380 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 $0.02 per unit to $9.68 per unit using a Black-Scholes model, iii) assumed discount rates ranging from 5.57% to 10.0% and iv) assumed growth rates of 1.0% .

Net Income (Loss) per Limited P

Net Income (Loss) per Limited Partner Unit	3 Months Ended
	Mar. 31, 2017
Earnings Per Share [Abstract]
Net Income (Loss) per Limited Partner Unit	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 income (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 March 31, 2017 2016 Net (loss) from continuing operations $ (28,881 ) $ (10,064 ) Less: Net income (loss) attributable to noncontrolling interests 1,303 (3 ) Net loss from continuing operations attributable to the Partnership (30,184 ) (10,061 ) Less: Distributions on Series A Units 4,296 4,471 Distributions on Series C Units 3,627 — Distributions on Series D Units 962 — General partner's distribution 200 2,028 General partner's share in undistributed loss (560 ) (418 ) Net loss from continuing operations attributable to Limited Partners (38,709 ) (16,142 ) Net loss from discontinued operations attributable to Limited Partners — (539 ) Net loss attributable to Limited Partners $ (38,709 ) $ (16,681 ) Weighted average number of common units used in computation of Limited Partners' net loss per common unit - basic and diluted 51,451 50,925 Limited Partners' net loss from continuing operations per unit $ (0.75 ) $ (0.32 ) Limited Partners' net loss from discontinued operations per unit — (0.01 ) Limited Partners' net loss per common unit (1) $ (0.75 ) $ (0.33 ) (1) Potential common unit equivalents are antidilutive for all periods and, as a result, have been excluded from the determination of diluted limited partners' net income (loss) per common unit.

Long-Term Incentive Plan

Long-Term Incentive Plan	3 Months Ended
	Mar. 31, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Long-Term Incentive Plan	Long-Term Incentive Plan Our General Partner manages our operations and activities and employs the personnel who provide support to our operations. On November 19, 2015, the Board of Directors of our General Partner approved the Third Amended and Restated Long-Term Incentive Plan to, 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, additional 312,716 common units were registered to be issued in relation to the converted JPE phantom units. 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 three months ended March 31, 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 (964 ) 30.14 Vested (319,572 ) 7.41 Outstanding units at March 31, 2017 1,240,299 $ 6.86 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 expense related to these awards for the three months ended March 31, 2017 and 2016 was $4.0 million and $1.6 million respectively, and is 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 $ 5.0 million and $0.9 million for the three months ended March 31, 2017 and 2016 , respectively.

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Legal proceedings We are not currently party to any pending litigation or governmental proceedings, other than ordinary routine litigation incidental to our business. While the ultimate impact of any proceedings cannot be predicted with certainty, our management believes that the resolution of any of our pending proceedings will not have a material adverse effect on our financial condition, 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, American Midstream (Midla), LLC ("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. Merger 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. We have estimated the fair value of the obligation to be approximately $3.4 million , which has been recorded as of March 31, 2017.

Related Party Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2017
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions 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 early 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 condensed consolidated financial statements as of March 31, 2017 . 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 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 million . The financial support will continue for eight ( 8 ) consecutive quarters following the closing of the merger, or if earlier, until $25 million in support has been provided. The General Partner would also reimburse the Partnership for certain expenses it incurs in connection with the post closing transition for one year. We have not currently utilized any of the financial support mentioned above. Separate from the financial support described above, our General Partner agreed to absorb $9.6 million corporate overhead expenses incurred by us in the first quarter of 2017 and not pass such expense through to us. 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 $0.3 million for each of the three months ended March 31, 2017 and March 31, 2016. As of March 31, 2017, we had a receivable balance due from Republic of $1.4 million , which is included in Receivables from related parties in the condensed consolidated balance sheet. As of March 31, 2017 and December 31, 2016, we had $1.3 million and $3.9 million , respectively, due to our General Partner, which has been recorded in Accrued expenses and other current liabilities and relates primarily to compensation. This payable is generally settled on a quarterly basis related to the foregoing transactions. On November 1, 2016, we became operator of the Destin and Okeanos pipelines and entered into an 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 three months ended March 31, 2017 , we recognized $0.6 million of management fee income. American Panther, LLC ("American Panther") is a 60% -owned subsidiary of us which is consolidated for financial reporting purposes. Pursuant to a related agreement which began in the second quarter of 2016, an affiliate of the non-controlling interest holder provides services to American Panther 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 statement of operations. During the three months ended March 31, 2017, we provided services for related fees which totaled $0.3 million of Direct operating expenses and $0.1 million of Corporate expenses in the unaudited condensed consolidated statement of operations. We enter into 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 March 31, 2017 , and 2016 , we recognized revenue of $0.7 million , and $0.9 million , respectively, while purchases from this company totaled $1.4 million , and $1.0 million , respectively. 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 three months ended March 31, 2016, which have been included in net loss from discontinued operations in the condensed consolidated statements of operations. We combined the cash flows from the MidContinent Business with the cash flows from continuing operations for all periods presented in the consolidated statements of cash flows. 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 $4.0 million and $2.5 million for the three months ended March 31, 2017 and 2016, respectively. JPE’s general partner agreed to absorb $1.5 million of such corporate overhead expenses in the three months ended March 31, 2016.

Reportable Segments

Reportable Segments	3 Months Ended
	Mar. 31, 2017
Segment Reporting [Abstract]
Reportable Segments	Reportable Segments During the first quarter of 2017, as a result of the acquisition of JPE described in Note 1, we realigned the composition of our reportable segments. Accordingly, we have restated the items of segment information for the three months ended March 31, 2016 to reflect this new segment adjustment. Our operations are located in the United States and are organized into six reportable segments: 1) Gas Gathering and Processing Services, 2) Liquid Pipelines and Services, 3) Natural Gas Transportation Services, 4) Offshore Pipeline and Services, 5) Terminalling Services, and 6) Propane Marketing 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. • Propane Marketing Services . Our Propane Marketing Services segment gathers, transports and sells natural gas liquids (NGLs). This is accomplished through cylinder tank exchange, sales through retail, commercial and wholesale distribution and through a fleet of trucks operating in the Eagle Ford and Permian basin areas. 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, Terminalling Services and Propane Marketing Services segments. 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. We define segment gross margin in our Propane Marketing Services segment as total revenue less purchases of natural gas, NGLs and condensate excluding non-cash charges such as non-cash unrealized gains or plus unrealized losses on commodity derivatives. A reconciliation from Segment Gross Margin to Net Income attributable to the Partnership for the periods ended March 31, 2017 and March 31, 2016 is below (in thousands): Three months ended March 31, 2017 2016 Reconciliation of Segment Gross Margin to Net income (loss) attributable to the Partnership: Gas Gathering and Processing Services segment gross margin $ 11,251 $ 11,619 Liquid Pipelines and Services segment gross margin 6,470 5,850 Natural Gas Transportation Services segment gross margin 6,119 5,563 Offshore Pipelines and Services segment gross margin 25,802 13,265 Terminalling Services segment gross margin (1) 11,160 9,443 Propane Marketing Services segment gross margin 19,302 28,305 Total Segment Gross Margin 80,104 74,045 Less: Other direct operating expenses (1) 27,015 27,966 Total Operating Margin 53,089 46,079 Plus: Loss on commodity derivatives, net (257 ) (238 ) Less: Corporate expenses 32,844 21,101 Depreciation, amortization and accretion expense 29,351 25,041 (Gain) loss on sale of assets, net (228 ) 1,122 Interest expense 17,966 8,302 Other income (14 ) (31 ) Other, net 671 (365 ) Income tax expense 1,123 735 Loss from discontinued operations, net of tax — 539 Net income (loss) attributable to noncontrolling interest 1,303 (3 ) Net income (loss) attributable to the Partnership $ (30,184 ) $ (10,600 ) _______________________ (1) Other direct operating expenses include Gas Gathering and Processing segment direct operating expenses of $8.1 million and $8.5 million , respectively, Liquid Pipelines and Services segment direct operating expenses of $2.1 million and $2.5 million , respectively, Natural Gas Transportation Services segment direct operating expenses of $1.2 million and $1.2 million , respectively, Offshore Pipelines and Services segment direct operating expenses of $2.6 million and $2.3 million , respectively, Propane Marketing Services segment direct operating expenses of $13.1 million and $13.5 million , respectively, for the three months ended March 31, 2017 and 2016 . Direct operating expenses related to our Terminalling Services segment of $3.1 million and $2.6 million for the three months ended March 31, 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 months ended March 31, 2017 and 2016 (in thousands): Three months ended March 31, 2017 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Propane Marketing Services Total Revenue $ 34,407 $ 82,039 $ 12,438 $ 14,831 $ 18,626 $ 37,548 $ 199,889 Gain (loss) on commodity derivatives, net (7 ) 372 — — — (622 ) (257 ) Total revenue 34,400 82,411 12,438 14,831 18,626 36,926 199,632 Earnings in unconsolidated affiliates — 1,088 — 14,314 — — 15,402 Operating expenses: Cost of Sales 23,187 77,077 6,260 3,343 4,393 18,525 132,785 Direct operating expenses 8,065 2,074 1,235 2,579 3,073 13,062 30,088 Corporate expenses 32,844 Depreciation, amortization and accretion expense 29,351 Gain on sale of assets, net (228 ) Total operating expenses 224,840 Interest expense 17,966 Other (income) expense (14 ) Loss from continuing operations before taxes (27,758 ) Income tax expense 1,123 Net loss (28,881 ) Less: Net income attributable to non-controlling interests 1,303 Net loss attributable to the Partnership $ (30,184 ) Segment gross margin $ 11,251 $ 6,470 $ 6,119 $ 25,802 $ 11,160 $ 19,302 Three months ended March 31, 2016 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Propane Marketing Services Total Revenue $ 23,295 $ 44,515 $ 9,795 $ 7,003 $ 14,393 $ 44,613 $ 143,614 Gain (loss) on commodity derivatives, net (103 ) (233 ) — — (175 ) — 273 (238 ) Total revenue 23,192 44,282 9,795 7,003 14,218 44,886 143,376 Earnings in unconsolidated affiliates — — — 7,343 — — 7,343 Operating expenses: Cost of Sales 11,707 38,654 4,224 1,081 2,205 16,067 73,938 Direct operating expenses 8,548 2,467 1,227 2,253 2,609 13,471 30,575 Corporate expenses 21,101 Depreciation, amortization and accretion expense 25,041 Loss on sale of assets, net 1,122 Total operating expenses 151,777 Interest expense 8,302 Other (income) expense (31 ) Loss from continuing operations before taxes (9,329 ) Income tax expense 735 Income (loss from continuing operation (10,064 ) Loss from discontinued operations, net of tax 539 Net loss (10,603 ) Less: Net loss attributable to non-controlling interests (3 ) Net loss attributable to the Partnership $ (10,600 ) Segment gross margin $ 11,619 $ 5,850 $ 5,563 $ 13,265 $ 9,443 $ 28,305 A reconciliation of total assets by segment to the amounts included in the condensed consolidated balance sheets follows: March 31, December 31, 2017 2016 Segment assets: Gas Gathering and Processing Services $ 390,334 $ 532,009 Liquid Pipelines and Services 447,121 422,636 Offshore Pipelines and Services 365,507 385,893 Natural Gas Transportation Services 176,740 221,604 Terminalling Services 277,632 299,534 Propane Marketing Services 134,604 140,864 Other (1) 254,305 346,781 Total assets $ 2,046,243 $ 2,349,321 (1) Other assets not allocable to segments consist of corporate leasehold improvements and other assets.

Subsequent Event

Subsequent Event	3 Months Ended
	Mar. 31, 2017
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Distribution On April 25, 2017, we announced that the Board of Directors of our General Partner declared a quarterly cash distribution of $0.4125 per common unit for the quarter ended March 31, 2017 , or $1.65 per common unit on an annualized basis. The distribution is expected to be paid on May 12, 2017, to unitholders of record as of the close of business on May 5, 2017.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information (Notes)	3 Months Ended
	Mar. 31, 2017
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Supplemental cash flows and non-cash transactions consist of the following (in thousands): Three months ended March 31, 2017 2016 Supplemental non-cash information Increase (decrease) in accrued property, plant and equipment purchases $ (1,371 ) $ 1,876 Contributions from General Partner 4,000 2,500 Accrued distributions on convertible preferred units 8,885 4,471 Paid-in-kind distributions on convertible preferred units 2,733 4,380 Cancellation of escrow units — 6,817

Organization, Basis of Presen28

Organization, Basis of Presentation and Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Business	Merger with JPE 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 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 both we and JPE were controlled by ArcLight affiliates, the acquisition represents 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 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. 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 six reportable segments, (1) gas gathering and processing services, (2) liquids pipelines and services, (3) natural gas transportation services, (4) offshore pipelines and services, (5) terminalling services and (6) propane marketing 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 distributing and selling propane and refined products. Most of our cash flow is generated from fee-based and fixed-margin compensation 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 transmission and terminal assets are in key demand markets in Oklahoma, Alabama, Arkansas, Louisiana, Mississippi and Tennessee and in the Port of New Orleans in Louisiana and the Port of Brunswick in Georgia. Our propane marketing services include commercial and retail operations across 46 of the lower 48 states.
Basis of Presentation	The unaudited financial information included in this Form 10-Q has been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2016, except that the consolidated financial statements have been retrospectively adjusted to reflect the consolidation of JPE, as discussed above. The results of operations for the three months ended March 31, 2017 is 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	Transactions between entities under common control We 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 will be 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, contracted arrangements and management restrictions. Such amounts are included in Restricted cash in our 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.
Investment in Unconsolidated Affiliates	Investment 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.
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 consolidated statements of operations.
New Accounting Pronouncements	New Accounting Pronouncements Accounting Standards Issued Not Yet Adopted In May 2014, the FASB issued 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. In March 2016, the FASB issued ASU No. 2016-08, Revenue from Contracts with Customers (Topic 606): Principal Versus Agent Considerations, as further clarification on principal versus agent considerations. In April 2016, the FASB issued 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. In May 2016, the FASB issued 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 that these updates will have on our consolidated financial statements and related disclosures. We have engaged a third-party consultant to assist with our review and are still in the process of evaluating the method of adoption for transitioning to the new standard. In February 2016, the FASB issued ASU No. 2016-02 (Topic 842) " Leases " which supersedes the lease recognition requirements in Accounting Standards Codification 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. Based upon our evaluation to date, we anticipate that the adoption of ASU 2016-02 will have a material effect 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 have not yet determined the timing or manner in which we will implement the updated guidance. 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. Early adoption is permitted, but only if all aspects are adopted in the same period. We are currently evaluating the impact this update will have on our consolidated statements of cash flows and related disclosures. 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 are currently evaluating the impact that this update will have on our consolidated statement of cash flows and related disclosures. 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 a “set” (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. The adoption of ASU 2017-01 is not expected to have a material impact on our consolidated financial statements and related disclosures associated with acquisitions subsequent to the effective date. 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 are currently evaluating the impact this update will have on our consolidated financial statements and related disclosures.

Inventory (Tables)

Inventory (Tables)	3 Months Ended
	Mar. 31, 2017
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventory consists of the following as of March 31, 2017 and December 31, 2016 (in thousands): March 31, 2017 December 31, 2016 Crude oil $ 3,969 $ 1,216 NGLs 3,505 3,482 Refined products 439 291 Materials, supplies and equipment 1,701 1,787 Total inventory $ 9,614 $ 6,776

Other Current Assets (Tables)

Other Current Assets (Tables)	3 Months Ended
	Mar. 31, 2017
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of Other Current Assets	Other current assets consist of the following (in thousands): March 31, 2017 December 31, 2016 Prepaid insurance $ 7,729 $ 9,702 Insurance receivables 7,574 2,895 Due from related parties 7,083 4,805 Other receivables 3,928 2,998 Risk management assets 534 964 Other assets 1,164 6,303 Total $ 28,012 $ 27,667

Risk Management Activities (Tab

Risk Management Activities (Tables)	3 Months Ended
	Mar. 31, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of notional amounts of outstanding derivative positions	The following table summarizes the net notional volume purchases (sales) of our outstanding commodity-related derivatives, excluding those contracts that qualified for the NPNS exception as of March 31, 2017 and December 31, 2016, none of which were designated as hedges for accounting purposes. March 31, 2017 December 31, 2016 Commodity Swaps Volume Maturity Volume Maturity Propane Fixed Price (Gallons) 7,767,296 April 30,2017 - December 31, 2019 4,364,880 January 31, 2017 - November 30, 2018 Crude Oil Fixed Price (Barrels) 61,000 May 31, 2017 - June 30, 2017 — — Crude Oil Basis (Barrels) — — 180,000 January 25, 2017- March 25, 2017 As of March 31, 2017 , our outstanding interest rate swap contracts consist of the following (in thousands): Notional Amount Term Fair Value $100,000 April 1, 2017 through December 29, 2017 $101 $100,000 December 29, 2017 through January 29, 2019 $287 $200,000 April 1, 2017 through September 3, 2019 $2,092 $100,000 January 1, 2018 through December 31, 2021 $2,847 $150,000 January 1, 2018 through December 31, 2022 $4,732 $10,059
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 as of March 31, 2017 and December 31, 2016 (in thousands): Asset Derivatives Liability Derivatives Type Balance Sheet Classification March 31, December 31, 2016 March 31, December 31, 2016 Commodity swaps Other current assets $ 200 $ 607 $ — $ — Commodity swaps Accrued expenses and other current liabilities — — (316 ) (1 ) Commodity swaps Risk management assets - long term 3 37 — — Commodity swaps Other liabilities — — (201 ) (1 ) Interest rate swaps Other current assets 337 — — — Interest rate swaps Accrued expenses and other current liabilities — — — (252 ) Interest rate swaps Risk management assets- long term 9,722 10,628 — — Weather derivatives Other current assets $ 172 $ 429 $ — $ — 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 as of March 31, 2017 and December 31, 2016 that are subject to enforceable master netting arrangements (in thousands): Gross Risk Management Position Netting Adjustments Net Risk Management Position presented in the balance sheet Balance Sheet Classification March 31, December 31, 2016 March 31, December 31, 2016 March 31, December 31, 2016 Other current assets $ 709 $ 1,036 $ (175 ) $ (72 ) $ 534 $ 964 Risk management assets- long term 9,725 10,665 (101 ) (1 ) 9,624 10,664 Total assets $ 10,434 $ 11,701 $ (276 ) $ (73 ) $ 10,158 $ 11,628 Accrued expenses and other liabilities $ (316 ) $ (253 ) $ 175 $ 72 $ (141 ) $ (181 ) Other liabilities (201 ) (1 ) 101 1 (100 ) — Total liabilities $ (517 ) $ (254 ) $ 276 $ 73 $ (241 ) $ (181 )
Realized and unrealized gains (losses) with commodity and interst rate derivative instruments	For the three months ended March 31, 2017 and 2016 , respectively, 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): Realized Unrealized 2017 Gains (losses) on commodity derivatives, net $ 699 $ (956 ) Interest expense (65 ) (317 ) Direct operating expenses (257 ) — Total $ 377 $ (1,273 ) 2016 Gains (losses) on commodity derivatives, net $ (388 ) $ 150 Interest expense — (1,532 ) Direct operating expenses (219 ) — Total $ (607 ) $ (1,382 )

Property, Plant and Equipment32

Property, Plant and Equipment, Net (Tables)	3 Months Ended
	Mar. 31, 2017
Property, Plant and Equipment [Abstract]
Property, plant and equipment, net	Property, plant and equipment, net, consists of the following (in thousands): Useful Life (in years) March 31, December 31, Land N/A $ 21,390 $ 21,811 Construction in progress N/A 117,288 131,449 Buildings and improvements 4 to 40 24,407 24,323 Transportation equipment 5 to 15 45,519 44,060 Processing and treating plants 8 to 40 139,553 137,014 Pipelines, compressors and right-of-way 3 to 40 776,867 754,911 Storage 3 to 40 210,685 210,579 Equipment 3 to 31 107,715 104,235 Total property, plant and equipment 1,443,424 1,428,382 Accumulated depreciation (301,122 ) (283,379 ) Property, plant and equipment, net $ 1,142,302 $ 1,145,003

Goodwill and Intangible Asset33

Goodwill and Intangible Assets, Net (Tables)	3 Months Ended
	Mar. 31, 2017
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Goodwill	Goodwill as of March 31, 2017 and December 31, 2016 consisted of the following (in thousands): March 31, December 31, Liquids Pipelines and Services $ 124,710 $ 124,710 Terminalling Services 77,425 77,425 Propane Marketing Services 15,363 15,363 $ 217,498 $ 217,498
Schedule of Finite-Lived Intangible Assets	Intangible assets, net, consist of the following (in thousands): March 31, 2017 Gross carrying amount Accumulated amortization Net carrying amount Customer relationships $ 133,503 $ (35,806 ) $ 97,697 Customer contracts 95,594 (35,634 ) 59,960 Dedicated acreage 53,350 (4,882 ) 48,468 Collaborative arrangements 11,884 (778 ) 11,106 Noncompete agreements 3,423 (3,175 ) 248 Other 751 (215 ) 536 Total $ 298,505 $ (80,490 ) $ 218,015 December 31, 2016 Gross carrying amount Accumulated amortization Net carrying amount Customer relationships $ 133,503 $ (31,471 ) $ 102,032 Customer contracts 95,594 (33,414 ) 62,180 Dedicated acreage 53,350 (4,439 ) 48,911 Collaborative arrangements 11,884 (601 ) 11,283 Noncompete agreements 3,423 (3,086 ) 337 Other 751 (211 ) 540 Total $ 298,505 $ (73,222 ) $ 225,283

Investment in unconsolidated 34

Investment in unconsolidated affiliates (Tables)	3 Months Ended
	Mar. 31, 2017
Equity Method Investments and Joint Ventures [Abstract]
Investments in and Advances to Affiliates	The following table presents the activity in our investments in unconsolidated affiliates (in thousands): Delta House (1) Emerald Transactions FPS OGL Destin Tri-States Okeanos Wilprise MPOG Total Ownership % at March 31, 2017 20.1 % 20.1 % 49.7 % 16.7 % 66.7 % 25.3 % 66.7 % Balances at December 31, 2016 $ 64,483 $ 25,450 $ 110,882 $ 55,022 $ 27,059 $ 4,944 $ 4,148 $ 291,988 Earnings in unconsolidated affiliates 7,088 3,636 2,126 899 1,572 188 (107 ) 15,402 Distributions (6,986 ) (3,555 ) (6,258 ) (1,100 ) (3,667 ) (228 ) (700 ) (22,494 ) Balances at March 31, 2017 $ 64,585 $ 25,531 $ 106,750 $ 54,821 $ 24,964 $ 4,904 $ 3,341 $ 284,896 (1) Represents direct and indirect ownership interests in Class A Units.
Equity Method Investments	The following tables present the summarized combined financial information for our equity investments (amounts represent 100% of investee financial information): Balance Sheets: March 31, 2017 December 31, 2016 Current assets $ 87,406 $ 120,600 Non-current assets 1,353,629 1,387,675 Current liabilities 62,231 64,099 Non-current liabilities $ 584,742 $ 623,650 Three months ended March 31, Statements of Operations: 2017 2016 Revenue $ 98,439 $ 65,542 Cost of sales and operating expenses 18,300 5,392 Gross profit 80,139 60,150 Income from continuing operations 58,595 55,548 Net income $ 58,595 $ 55,548

Accrued Expenses and Other Cu35

Accrued Expenses and Other Current Liabilities (Tables)	3 Months Ended
	Mar. 31, 2017
Other Liabilities Disclosure [Abstract]
Schedule of Accrued Liabilities	Accrued expenses and other current liabilities consists of the following (in thousands): March 31, 2017 December 31, 2016 Capital expenditures $ 11,302 $ 14,499 Accrued interest 8,526 5,743 Convertible preferred unit distributions 6,707 7,103 Employee compensation 7,881 10,804 Current portion of asset retirement obligation 6,499 6,499 Legal accrual 5,150 — Additional Blackwater acquisition consideration 5,000 5,000 Transaction costs 4,539 3,000 Royalties payable 3,597 3,926 Escrow settlement 3,135 — Customer deposits 2,083 3,080 Taxes payable 1,809 1,066 Due to related parties 1,523 4,072 Gas imbalances payable 1,454 1,098 Deferred financing costs — 2,743 Recoverable gas costs 393 1,126 Other 11,289 11,525 $ 80,887 $ 81,284

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 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 three months ended March 31, 2017 (in thousands): Non-current balance $ 44,363 Current balance 6,499 Balances at December 31, 2016 $ 50,862 Expenditures (41 ) Accretion expense 487 Balances at March 31, 2017 $ 51,308 Less: current portion 6,499 Noncurrent asset retirement obligation $ 44,809

Debt Obligations (Tables)

Debt Obligations (Tables)	3 Months Ended
	Mar. 31, 2017
Debt Disclosure [Abstract]
Outstanding borrowings under the credit facility	Our outstanding debt consists of the following (in thousands): March 31, 2017 December 31, 2016 Revolving credit facility $ 644,842 $ 888,250 8.5% Senior Notes, due 2021 300,000 300,000 3.77% Senior Notes, due 2031 (Non-Recourse) 60,000 60,000 Other debt 1,546 3,809 Total debt obligations 1,006,388 1,252,059 Unamortized debt issuance costs (1) (10,228 ) (11,036 ) Total debt 996,160 1,241,023 Less: Current portion, including unamortized debt issuance costs (3,223 ) (5,485 ) Long term debt $ 992,937 $ 1,235,538 (1) Unamortized deferred financing costs related to the Credit Agreement are included in our condensed consolidated balance sheets in Other assets, net.

Convertible Preferred Units (Ta

Convertible Preferred Units (Tables)	3 Months Ended
	Mar. 31, 2017
Partners' Capital [Abstract]
Schedule of Preferred Units	Our convertible preferred units consist of the following (in thousands): Series A Series C Series D Units $ Units $ Units $ December 31, 2016 10,107 $ 181,386 8,792 $ 118,229 2,333 $ 34,475 Paid in kind unit distributions 159 2,181 — — — — March 31, 2017 10,266 $ 183,567 8,792 $ 118,229 2,333 $ 34,475

Partners Capital (Tables)

Partners Capital (Tables)	3 Months Ended
	Mar. 31, 2017
Equity [Abstract]
Schedule of Units Outstanding and Distributions	We made the following distributions (in thousands): Three months ended March 31, 2017 2016 Series A Units Cash Paid $ 2,527 $ — Accrued 4,296 4,471 Paid-in-kind units 2,733 4,380 Series C Units Cash Paid 3,627 — Accrued 3,627 — Series D Units Cash Paid 962 — Accrued 962 — Limited Partner Units Cash Paid 24,915 27,000 General Partner Units Cash Paid 167 2,028 Summary Cash Paid 32,198 29,028 Accrued 8,885 4,471 Paid-in-kind units 2,733 4,380 The following table presents unit activity (in thousands): General Limited Partner Interest Balances at December 31, 2016 680 51,351 LTIP vesting — 259 Issuance of common units — 21 Issuance of GP units 8 — Balances at March 31, 2017 688 51,631

Net Income (Loss) per Limited40

Net Income (Loss) per Limited Partner Unit (Tables)	3 Months Ended
	Mar. 31, 2017
Earnings Per Share [Abstract]
Schedule of Calculation for Net Income (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 March 31, 2017 2016 Net (loss) from continuing operations $ (28,881 ) $ (10,064 ) Less: Net income (loss) attributable to noncontrolling interests 1,303 (3 ) Net loss from continuing operations attributable to the Partnership (30,184 ) (10,061 ) Less: Distributions on Series A Units 4,296 4,471 Distributions on Series C Units 3,627 — Distributions on Series D Units 962 — General partner's distribution 200 2,028 General partner's share in undistributed loss (560 ) (418 ) Net loss from continuing operations attributable to Limited Partners (38,709 ) (16,142 ) Net loss from discontinued operations attributable to Limited Partners — (539 ) Net loss attributable to Limited Partners $ (38,709 ) $ (16,681 ) Weighted average number of common units used in computation of Limited Partners' net loss per common unit - basic and diluted 51,451 50,925 Limited Partners' net loss from continuing operations per unit $ (0.75 ) $ (0.32 ) Limited Partners' net loss from discontinued operations per unit — (0.01 ) Limited Partners' net loss per common unit (1) $ (0.75 ) $ (0.33 ) (1) Potential common unit equivalents are antidilutive for all periods and, as a result, have been excluded from the determination of diluted limited partners' net income (loss) per common unit.

Long-Term Incentive Plan (Table

Long-Term Incentive Plan (Tables)	3 Months Ended
	Mar. 31, 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 three months ended March 31, 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 (964 ) 30.14 Vested (319,572 ) 7.41 Outstanding units at March 31, 2017 1,240,299 $ 6.86

Reportable Segments (Tables)

Reportable Segments (Tables)	3 Months Ended
	Mar. 31, 2017
Segment Reporting [Abstract]
Segment information	A reconciliation from Segment Gross Margin to Net Income attributable to the Partnership for the periods ended March 31, 2017 and March 31, 2016 is below (in thousands): Three months ended March 31, 2017 2016 Reconciliation of Segment Gross Margin to Net income (loss) attributable to the Partnership: Gas Gathering and Processing Services segment gross margin $ 11,251 $ 11,619 Liquid Pipelines and Services segment gross margin 6,470 5,850 Natural Gas Transportation Services segment gross margin 6,119 5,563 Offshore Pipelines and Services segment gross margin 25,802 13,265 Terminalling Services segment gross margin (1) 11,160 9,443 Propane Marketing Services segment gross margin 19,302 28,305 Total Segment Gross Margin 80,104 74,045 Less: Other direct operating expenses (1) 27,015 27,966 Total Operating Margin 53,089 46,079 Plus: Loss on commodity derivatives, net (257 ) (238 ) Less: Corporate expenses 32,844 21,101 Depreciation, amortization and accretion expense 29,351 25,041 (Gain) loss on sale of assets, net (228 ) 1,122 Interest expense 17,966 8,302 Other income (14 ) (31 ) Other, net 671 (365 ) Income tax expense 1,123 735 Loss from discontinued operations, net of tax — 539 Net income (loss) attributable to noncontrolling interest 1,303 (3 ) Net income (loss) attributable to the Partnership $ (30,184 ) $ (10,600 ) _______________________ (1) Other direct operating expenses include Gas Gathering and Processing segment direct operating expenses of $8.1 million and $8.5 million , respectively, Liquid Pipelines and Services segment direct operating expenses of $2.1 million and $2.5 million , respectively, Natural Gas Transportation Services segment direct operating expenses of $1.2 million and $1.2 million , respectively, Offshore Pipelines and Services segment direct operating expenses of $2.6 million and $2.3 million , respectively, Propane Marketing Services segment direct operating expenses of $13.1 million and $13.5 million , respectively, for the three months ended March 31, 2017 and 2016 . Direct operating expenses related to our Terminalling Services segment of $3.1 million and $2.6 million for the three months ended March 31, 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 months ended March 31, 2017 and 2016 (in thousands): Three months ended March 31, 2017 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Propane Marketing Services Total Revenue $ 34,407 $ 82,039 $ 12,438 $ 14,831 $ 18,626 $ 37,548 $ 199,889 Gain (loss) on commodity derivatives, net (7 ) 372 — — — (622 ) (257 ) Total revenue 34,400 82,411 12,438 14,831 18,626 36,926 199,632 Earnings in unconsolidated affiliates — 1,088 — 14,314 — — 15,402 Operating expenses: Cost of Sales 23,187 77,077 6,260 3,343 4,393 18,525 132,785 Direct operating expenses 8,065 2,074 1,235 2,579 3,073 13,062 30,088 Corporate expenses 32,844 Depreciation, amortization and accretion expense 29,351 Gain on sale of assets, net (228 ) Total operating expenses 224,840 Interest expense 17,966 Other (income) expense (14 ) Loss from continuing operations before taxes (27,758 ) Income tax expense 1,123 Net loss (28,881 ) Less: Net income attributable to non-controlling interests 1,303 Net loss attributable to the Partnership $ (30,184 ) Segment gross margin $ 11,251 $ 6,470 $ 6,119 $ 25,802 $ 11,160 $ 19,302 Three months ended March 31, 2016 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Propane Marketing Services Total Revenue $ 23,295 $ 44,515 $ 9,795 $ 7,003 $ 14,393 $ 44,613 $ 143,614 Gain (loss) on commodity derivatives, net (103 ) (233 ) — — (175 ) — 273 (238 ) Total revenue 23,192 44,282 9,795 7,003 14,218 44,886 143,376 Earnings in unconsolidated affiliates — — — 7,343 — — 7,343 Operating expenses: Cost of Sales 11,707 38,654 4,224 1,081 2,205 16,067 73,938 Direct operating expenses 8,548 2,467 1,227 2,253 2,609 13,471 30,575 Corporate expenses 21,101 Depreciation, amortization and accretion expense 25,041 Loss on sale of assets, net 1,122 Total operating expenses 151,777 Interest expense 8,302 Other (income) expense (31 ) Loss from continuing operations before taxes (9,329 ) Income tax expense 735 Income (loss from continuing operation (10,064 ) Loss from discontinued operations, net of tax 539 Net loss (10,603 ) Less: Net loss attributable to non-controlling interests (3 ) Net loss attributable to the Partnership $ (10,600 ) Segment gross margin $ 11,619 $ 5,850 $ 5,563 $ 13,265 $ 9,443 $ 28,305 A reconciliation of total assets by segment to the amounts included in the condensed consolidated balance sheets follows: March 31, December 31, 2017 2016 Segment assets: Gas Gathering and Processing Services $ 390,334 $ 532,009 Liquid Pipelines and Services 447,121 422,636 Offshore Pipelines and Services 365,507 385,893 Natural Gas Transportation Services 176,740 221,604 Terminalling Services 277,632 299,534 Propane Marketing Services 134,604 140,864 Other (1) 254,305 346,781 Total assets $ 2,046,243 $ 2,349,321 (1) Other assets not allocable to segments consist of corporate leasehold improvements and other assets.

Supplemental Cash Flow Inform43

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 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): Three months ended March 31, 2017 2016 Supplemental non-cash information Increase (decrease) in accrued property, plant and equipment purchases $ (1,371 ) $ 1,876 Contributions from General Partner 4,000 2,500 Accrued distributions on convertible preferred units 8,885 4,471 Paid-in-kind distributions on convertible preferred units 2,733 4,380 Cancellation of escrow units — 6,817

Organization, Basis of Presen44

Organization, Basis of Presentation and Summary of Significant Accounting Policies (Details) $ in Thousands, shares in Millions	3 Months Ended
	Mar. 31, 2017USD ($)segments	Mar. 31, 2016USD ($)	Mar. 08, 2017shares	Dec. 31, 2016USD ($)	Dec. 28, 2016
Debt Instrument [Line Items]
Number of Reportable Segments | segments	6
Income tax expense | $	$ 1,123	$ 735
General partners' capital account, percentage	77.00%
Limited partners' capital account, percentage	23.00%
Repayments of lines of credit | $	$ 325,908	$ 59,450
Allowance for doubtful accounts receivable | $	$ 2,480			$ 1,871
Senior Notes [Member] | 8.50% Senior Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			8.50%
Senior Notes [Member] | Senior Notes, Due 2021 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					8.50%
General Partner [Member]
Debt Instrument [Line Items]
General Partners' Capital Account, Units Issued			20.2
Affiliated Entity [Member] | General Partner [Member]
Debt Instrument [Line Items]
General Partners' Capital Account, Units Issued			9.8
JPE Energy Partners [Member]
Debt Instrument [Line Items]
General Partners' Capital Account, Units Issued			20.2
JPE Energy Partners [Member] | Affiliated Entity [Member]
Debt Instrument [Line Items]
General Partners' Capital Account, Units Issued			9.8

Acquisitions (Narrative) (Detai

Acquisitions (Narrative) (Details) shares in Millions	Mar. 08, 2017business_segmentshares
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 Partners' Capital Account, Units Issued	20.2
Affiliated Entity [Member] | General Partner [Member]
Business Acquisition [Line Items]
General Partners' Capital Account, Units Issued	9.8
JPE Energy Partners [Member]
Business Acquisition [Line Items]
Number of operating segments | business_segment	3

Inventory (Details)

Inventory (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Inventory Disclosure [Abstract]
Crude oil	$ 3,969	$ 1,216
NGLs	3,505	3,482
Refined products	439	291
Materials, supplies and equipment	1,701	1,787
Total inventory	$ 9,614	$ 6,776

Other Current Assets (Details)

Other Current Assets (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Prepaid insurance	$ 7,729	$ 9,702
Insurance receivables	7,574	2,895
Other receivables	3,928	2,998
Other assets	1,164	6,303
Due from related parties	7,083	4,805
Risk management assets	534	964
Total	$ 28,012	$ 27,667

Risk Management Activities (Com

Risk Management Activities (Commodity-related Derivatives) (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2017bblgal	Dec. 31, 2016bblgal
Propane [Member] | Propane, Fixed Price Commodity Swap Contract [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | gal	7,767,296,000	4,364,880,000
Crude Oil [Member] | Crude Oil, Fixed Price Commodity Swap Contract [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	61,000,000	0
Crude Oil [Member] | Propane, Basis Commodity Swap Contract [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0	180,000,000

Risk Management Activities (Int

Risk Management Activities (Interest Rate Swaps) (Details) - Interest Rate Swap [Member]	Mar. 31, 2017USD ($)
Derivative [Line Items]
Fair Value	$ 10,059,000
April 1, 2017 through December 29, 2017
Derivative [Line Items]
Notional Amount	100,000,000
Fair Value	101,000
April 1, 2017 through September 3, 2019
Derivative [Line Items]
Notional Amount	100,000,000
Fair Value	287,000
January 1, 2018 through December 31, 2021
Derivative [Line Items]
Notional Amount	200,000,000
Fair Value	2,092,000
January 1, 2018 through December 31, 2022
Derivative [Line Items]
Notional Amount	100,000,000
Fair Value	2,847,000
Wells Fargo Swap 5 [Member]
Derivative [Line Items]
Notional Amount	150,000,000
Fair Value	$ 4,732,000

Risk Management Activities (Fai

Risk Management Activities (Fair Value of Commodity Derivatives) (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Derivative Asset [Abstract]
Gross Risk Management Position	$ 10,434	$ 11,701
Netting Adjustments	(276)	(73)
Net Risk Management Position presented in the balance sheet	10,158	11,628
Derivative Liability [Abstract]
Gross Risk Management Position	276	73
Netting Adjustments	(517)	(254)
Net Risk Management Position presented in the balance sheet	(241)	(181)
Other Current Assets [Member] | Commodity derivatives [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	200	607
Derivative Liability [Abstract]
Gross Risk Management Position	0	0
Other Current Assets [Member] | Interest Rate Swap [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	337	0
Derivative Liability [Abstract]
Gross Risk Management Position	0	0
Other Current Assets [Member] | Weather Derivative [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	172	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	(316)	(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	709	1,036
Netting Adjustments	(175)	(72)
Net Risk Management Position presented in the balance sheet	534	964
Risk Management Assets - Long Term [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	9,725	10,665
Netting Adjustments	(101)	(1)
Net Risk Management Position presented in the balance sheet	9,624	10,664
Risk Management Assets - Long Term [Member] | Commodity derivatives [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	3	37
Derivative Liability [Abstract]
Gross Risk Management Position	0	0
Risk Management Assets - Long Term [Member] | Interest Rate Swap [Member]
Derivative Asset [Abstract]
Gross Risk Management Position	9,722	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	(201)	(1)
Risk Management Liabilities [Member]
Derivative Liability [Abstract]
Gross Risk Management Position	(316)	(253)
Netting Adjustments	175	72
Net Risk Management Position presented in the balance sheet	(141)	(181)
Risk Management Liabilities - Long Term [Member]
Derivative Liability [Abstract]
Gross Risk Management Position	(201)	(1)
Netting Adjustments	101	1
Net Risk Management Position presented in the balance sheet	$ (100)	$ 0

Risk Management Activities (Rea

Risk Management Activities (Realized and Unrealized Gains (Losses)) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Derivatives, Fair Value [Line Items]
Gain (loss) on commodity derivatives, net	$ (257)	$ (238)
Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Gain (loss) on commodity derivatives, net	377	(607)
Unrealized gain (loss) on derivatives	(1,273)	(1,382)
Gain (Loss) on Derivative Instruments [Member] | Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Gain (loss) on commodity derivatives, net	699	(388)
Unrealized gain (loss) on derivatives	(956)	150
Interest Expense [Member] | Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Gain (loss) on commodity derivatives, net	(65)	0
Unrealized gain (loss) on derivatives	(317)	(1,532)
Direct operating expenses [Member] | Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Gain (loss) on commodity derivatives, net	(257)	(219)
Unrealized gain (loss) on derivatives	$ 0	$ 0

Risk Management Activities (Det

Risk Management Activities (Details Textual) - USD ($)	3 Months Ended
	Mar. 31, 2017	Jun. 30, 2016	Dec. 31, 2016
Weather Contract [Member]
Derivative [Line Items]
Potential proceeds from derivative contract		$ 30,000,000
Derivative term of contract	1 year
Debt instrument, unamortized premium	$ 200,000		$ 400,000
April 1, 2017 through December 29, 2017 | Interest Rate Swap [Member]
Derivative [Line Items]
Notional Amount	100,000,000
April 1, 2017 through September 3, 2019 | Interest Rate Swap [Member]
Derivative [Line Items]
Notional Amount	$ 100,000,000

Property, Plant and Equipment53

Property, Plant and Equipment, Net (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	$ 1,443,424	$ 1,428,382
Accumulated depreciation	(301,122)	(283,379)
Property, plant and equipment, net	1,142,302	1,145,003
Land [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	21,390	21,811
Construction in progress [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	117,288	131,449
Buildings and improvements [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	24,407	24,323
Transportation equipment [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	45,519	44,060
Processing and treating plants [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	139,553	137,014
Pipelines and compressors [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	776,867	754,911
Storage [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	210,685	210,579
Equipment [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment gross	$ 107,715	$ 104,235
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 and compressors [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life	40 years
Maximum [Member] | Office furniture and fixtures [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life	10 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	20 years
Minimum [Member] | Buildings and improvements [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life	4 years
Minimum [Member] | 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 and compressors [Member]
Property, Plant and Equipment, Net [Abstract]
Property plant and equipment in useful life	3 years
Minimum [Member] | Office furniture and fixtures [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	5 years

Property, Plant and Equipment (

Property, Plant and Equipment (Details Textual) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	$ 1,443,424		$ 1,428,382
Interest costs capitalized	1,000	$ 500
Depreciation	21,600
FERC Regulated Assets [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	$ 305,100		$ 291,100

Goodwill and Intangible Asset55

Goodwill and Intangible Assets, Net (Schedule of Goodwill) (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Goodwill [Line Items]
Goodwill	$ 217,498	$ 217,498
Liquid Pipelines and Services [Member]
Goodwill [Line Items]
Goodwill	124,710	124,710
Terminalling Services [Member]
Goodwill [Line Items]
Goodwill	77,425	77,425
Propane Marketing Services [Member]
Goodwill [Line Items]
Goodwill	$ 15,363	$ 15,363

Goodwill and Intangible Asset56

Goodwill and Intangible Assets, Net Goodwill and Intangible Assets, Net (Details Textual) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 7.3	$ 5.2
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	30 years

Goodwill and Intangible Asset57

Goodwill and Intangible Assets, Net Schedule of Intangible Assets (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Finite-Lived Intangible Assets [Line Items]
Customer relationships	$ 298,505	$ 298,505
Finite-Lived Intangible Assets, Accumulated Amortization	(80,490)	(73,222)
Finite-Lived Intangible Assets, Net	218,015	225,283
Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Customer relationships	133,503	133,503
Finite-Lived Intangible Assets, Accumulated Amortization	(35,806)	(31,471)
Finite-Lived Intangible Assets, Net	97,697	102,032
Customer Contracts [Member]
Finite-Lived Intangible Assets [Line Items]
Customer relationships	95,594	95,594
Finite-Lived Intangible Assets, Accumulated Amortization	(35,634)	(33,414)
Finite-Lived Intangible Assets, Net	59,960	62,180
Dedicated Acreage [Member]
Finite-Lived Intangible Assets [Line Items]
Customer relationships	53,350	53,350
Finite-Lived Intangible Assets, Accumulated Amortization	(4,882)	(4,439)
Finite-Lived Intangible Assets, Net	48,468	48,911
Collaborative Arrangement [Member]
Finite-Lived Intangible Assets [Line Items]
Customer relationships	11,884	11,884
Finite-Lived Intangible Assets, Accumulated Amortization	(778)	(601)
Finite-Lived Intangible Assets, Net	11,106	11,283
Noncompete Agreements [Member]
Finite-Lived Intangible Assets [Line Items]
Customer relationships	3,423	3,423
Finite-Lived Intangible Assets, Accumulated Amortization	(3,175)	(3,086)
Finite-Lived Intangible Assets, Net	248	337
Other Intangible Assets [Member]
Finite-Lived Intangible Assets [Line Items]
Customer relationships	751	751
Finite-Lived Intangible Assets, Accumulated Amortization	(215)	(211)
Finite-Lived Intangible Assets, Net	$ 536	$ 540

Investment in unconsolidated 58

Investment in unconsolidated affiliates Partnership's Equity Investments (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances	$ 291,988
Earnings in unconsolidated affiliates	15,402	$ 7,343
Distributions	(22,494)
Balances	$ 284,896
FPS [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage	20.10%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances	$ 64,483
Earnings in unconsolidated affiliates	7,088
Distributions	(6,986)
Balances	$ 64,585
OGL [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage	20.10%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances	$ 25,450
Earnings in unconsolidated affiliates	3,636
Distributions	(3,555)
Balances	$ 25,531
Destin [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage	49.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances	$ 110,882
Earnings in unconsolidated affiliates	2,126
Distributions	(6,258)
Balances	$ 106,750
Tri-State [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage	16.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances	$ 55,022
Earnings in unconsolidated affiliates	899
Distributions	(1,100)
Balances	$ 54,821
Okeanos [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage	66.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances	$ 27,059
Earnings in unconsolidated affiliates	1,572
Distributions	(3,667)
Balances	$ 24,964
Wilprise [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage	25.30%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances	$ 4,944
Earnings in unconsolidated affiliates	188
Distributions	(228)
Balances	$ 4,904
MPOG [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage	66.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances	$ 4,148
Earnings in unconsolidated affiliates	(107)
Distributions	(700)
Balances	$ 3,341

Investment in unconsolidated 59

Investment in unconsolidated affiliates Financial Information for the Partnership's Equity Investments - Balance Sheets (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
Current assets	$ 87,406	$ 120,600
Non-current assets	1,353,629	1,387,675
Current liabilities	62,231	64,099
Non-current liabilities	$ 584,742	$ 623,650

Investment in unconsolidated 60

Investment in unconsolidated affiliates Financial Information for the Partnership's Equity Investments - Statement of Operations (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
Revenue	$ 98,439	$ 65,542
Cost of sales and operating expenses	18,300	5,392
Gross profit	80,139	60,150
Income from continuing operations	58,595	55,548
Net income	$ 58,595	$ 55,548

Accrued Expenses and Other Cu61

Accrued Expenses and Other Current Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Other Liabilities Disclosure [Abstract]
Capital expenditures	$ 11,302	$ 14,499
Accrued interest	8,526	5,743
Convertible preferred unit distributions	6,707	7,103
Employee compensation	7,881	10,804
Current portion of asset retirement obligation	6,499	6,499
Legal accrual	5,150	0
Additional Blackwater acquisition consideration	5,000	5,000
Transaction costs	4,539	3,000
Royalties payable	3,597	3,926
Escrow settlement	3,135	0
Customer deposits	2,083	3,080
Taxes payable	1,809	1,066
Due to related parties	1,523	4,072
Gas imbalances payable	1,454	1,098
Deferred financing costs	0	2,743
Recoverable gas costs	393	1,126
Other	11,289	11,525
Accrued expenses and other current liabilities	$ 80,887	$ 81,284

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2017	Dec. 31, 2016
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Non-current balance		$ 44,809	$ 44,363
Current portion of asset retirement obligation		6,499	6,499
Balances at December 31, 2016	$ 50,862
Expenditures	(41)
Accretion expense	487
Balances at March 31, 2017	$ 50,862	51,308	50,862
Less: current portion		6,499	6,499
Noncurrent asset retirement obligation		44,809	44,363
Restricted cash and cash equivalents		$ 5,000	$ 5,000

Debt Obligations (Details)

Debt Obligations (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Revolving credit facility	$ 644,842	$ 888,250
Long-term	1,006,388	1,252,059
Unamortized debt issuance costs	(10,228)	(11,036)
Total debt obligations	996,160	1,241,023
Less: current portion	(3,223)	(5,485)
Long-term debt	992,937	1,235,538
Senior Notes [Member] | 8.50% Senior Notes [Member]
Debt Instrument [Line Items]
Long-term	300,000	300,000
Senior Notes [Member] | 3.77% Senior Notes [Member]
Debt Instrument [Line Items]
Long-term	60,000	60,000
Other Debt Obligations [Member]
Debt Instrument [Line Items]
Long-term	1,546	3,809
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Revolving credit facility	$ 644,842	$ 888,250

Debt Obligations (Details Textu

Debt Obligations (Details Textual)	Mar. 08, 2017USD ($)	Dec. 28, 2016USD ($)	Mar. 31, 2017USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Apr. 25, 2016USD ($)
Debt Instrument [Line Items]
Line of credit facility, current borrowing capacity							$ 750,000,000
Proceeds from Issuance of Long-term Debt and Capital Securities, Net		$ 294,000,000
Debt Issuance Costs, Gross		6,000,000
Additional Debt Issuance Costs		$ 2,700,000
Revolving credit agreement			$ 644,842,000		$ 888,250,000
Repayments of lines of credit			325,908,000	$ 59,450,000
Other			(20,000)	$ (44,000)
8.50% Senior Notes [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	8.50%
Long-term Debt, Fair Value			$ 305,600,000
Senior Notes, Due 2021 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		8.50%
Proceeds from Issuance of Senior Long-term Debt		$ 291,300,000
3.77% Senior Notes [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			3.77%
Long-term Debt, Fair Value			$ 54,600,000
Debt instrument, face amount						$ 60,000,000
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,100,000,000
Line of credit facility, current borrowing capacity	$ 900,000,000
Line of credit facility, unused capacity, commitment fee percentage			0.50%
Debt Instrument, Covenants, Adjusted Consolidated EBITDA	5		5.50
Debt Instrument Covenant, Consolidated Secured Leverage Ratio			3.50
Debt instrument, interest coverage ratio			6.19
Debt, weighted average interest rate			4.44%	4.07%
Revolving credit agreement			$ 644,842,000		$ 888,250,000
Line of Credit Facility, Remaining Borrowing Capacity			$ 670,700,000
Debt Instrument, Consolidated Total Leverage Ratio			4.64
Debt Instrument Covenant Consolidated Interest Coverage Ratio			2.50
Revolving Credit Facility [Member] | Base Rate [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Iinstrument, basis spread on variable rate			3.25%
Revolving Credit Facility [Member] | Base Rate [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Iinstrument, 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 Iinstrument, basis spread on variable rate			2.25%
Revolving Credit Facility [Member] | Eurodollar [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Iinstrument, basis spread on variable rate			1.00%
Letter of Credit [Member]
Debt Instrument [Line Items]
Revolving credit agreement			$ 25,900,000
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) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2017USD ($)shares
Increase (Decrease) in Partners' Capital [Roll Forward]
Convertible preferred units, Beginning Balance, Amount,	$ 334,090
Convertible preferred units, Ending Balance, Amount,	$ 336,271
Series A [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Convertible preferred units, Beginning Balance, Units | shares	10,107
Convertible preferred units, Ending Balance, Units | shares	10,266
Convertible preferred units, Beginning Balance, Amount,	$ 181,386
Convertible preferred units, Ending Balance, Amount,	$ 183,567
Series A [Member] | Unit Distribution [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Paid in kind unit distributions, Units | shares	159
Paid in kind unit distributions, Amount	$ 2,181
Series C [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Convertible preferred units, Beginning Balance, Units | shares	8,792
Convertible preferred units, Ending Balance, Units | shares	8,792
Convertible preferred units, Beginning Balance, Amount,	$ 118,229
Convertible preferred units, Ending Balance, Amount,	$ 118,229
Series C [Member] | Unit Distribution [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Paid in kind unit distributions, Units | shares	0
Paid in kind unit distributions, Amount	$ 0
Series D [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Convertible preferred units, Beginning Balance, Units | shares	2,333
Convertible preferred units, Ending Balance, Units | shares	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 | shares	0
Paid in kind unit distributions, Amount	$ 0

Convertible Preferred Units (De

Convertible Preferred Units (Details) - USD ($)	Apr. 25, 2016	Apr. 15, 2013	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Oct. 31, 2016	Jul. 27, 2015
Series A [Member]
Preferred Units [Line Items]
Partners' Capital Account, Units, Sale of Units, Percentage		90.00%
Partners' Capital Account, Units		5,142,857	10,266,000	10,107,000
Series A-2 [Member]
Preferred Units [Line Items]
Convertible Preferred Stock, Shares Issued upon Conversion			1.1027
Investment options, exercise price (in usd per share)			$ 15.87	$ 17.50
Call Right defined acquisition value							$ 100,000,000
Issuance of Series A Units, net of issuance costs					$ 45,000,000
Series A [Member]
Preferred Units [Line Items]
Partners' Capital Account, Distribution Per Unit of Limited Partner Interest		$ 0.4125	$ 0.4125
Convertible Preferred Stock, Shares Issued upon Conversion			1.1027
Investment options, exercise price (in usd per share)			$ 15.87
Series C [Member]
Preferred Units [Line Items]
Partners' Capital Account, Units			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
Fair Value Assumptions, 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]
Convertible Preferred Stock, Shares Issued upon Conversion	1		1.0036
Investment options, exercise price (in usd per share)			$ 13.95
Series D [Member]
Preferred Units [Line Items]
Partners' Capital Account, Units			2,333,000	2,333,000
Partners' Capital Account, Distribution Per Unit of Limited Partner Interest			$ 0.4125
Convertible Preferred Stock, Shares Issued upon Conversion						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
Limited Partners' Capital Account, Units Issued, Closing Fee, Percent						1.50%
Series D [Member]
Preferred Units [Line Items]
Class of warrant, exercise price of warrants (in usd per share)			$ 15
High Point Infrastructure Partners, LLC [Member] | Series A [Member]
Preferred Units [Line Items]
Total Consideration for Issuance of Preferred 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

Partners_ Capital Outstanding U

Partners’ Capital Outstanding Units (Details) shares in Thousands	3 Months Ended
	Mar. 31, 2017shares
Class of Stock [Line Items]
Balances at December 31, 2016	680
Balances at December 31, 2016	51,351
Balances at March 31, 2017	688
Balances at March 31, 2017	51,631
General Partner [Member] | Long Term Incentive Plan [Member]
Class of Stock [Line Items]
Partners' Capital Account Increase	0
General Partner [Member] | Limited Partner Common Units [Member]
Class of Stock [Line Items]
Partners' Capital Account Increase	0
General Partner [Member] | General Partner Units [Member]
Class of Stock [Line Items]
Partners' Capital Account Increase	8
Limited Partner [Member] | Long Term Incentive Plan [Member]
Class of Stock [Line Items]
Partners' Capital Account Increase	259
Limited Partner [Member] | Limited Partner Common Units [Member]
Class of Stock [Line Items]
Partners' Capital Account Increase	21
Limited Partner [Member] | General Partner Units [Member]
Class of Stock [Line Items]
Partners' Capital Account Increase	0

Partners Capital (Details Textu

Partners Capital (Details Textual) - USD ($) $ / shares in Units, $ in Thousands		Apr. 25, 2017	Mar. 31, 2017	Mar. 31, 2016	Mar. 08, 2017
Class of Stock [Line Items]
General partner interest			0.90%
Limited partner interests			99.10%
Contributions			$ 4,000	$ 2,500
Distribution declared per common unit (in usd per share)	[1]		$ 0.4125	$ 0.4725
Fair Value Inputs, Long-term Revenue Growth Rate			1.00%
Contributions			$ 123	$ 92
Series C [Member]
Class of Stock [Line Items]
Investment options, exercise price (in usd per share)			$ 13.95
General Partner [Member]
Class of Stock [Line Items]
Contributions			$ 123	$ 92
General partner interest, units issued (in shares)					20,200,000
Contributions			$ 100
Partners' Capital Account Increase			8,665	6,225
Subsequent Event [Member]
Class of Stock [Line Items]
Distribution declared per common unit (in usd per share)		$ 0.4125
Distribution made to limited partner, distributions declared, per unit, annualized basis (in usd per share)		$ 1.65
Minimum [Member]
Class of Stock [Line Items]
Fair value inputs, discount rate			5.57%
Fair value input, option value			$ 0.02
Maximum [Member]
Class of Stock [Line Items]
Fair value inputs, discount rate			10.00%
Fair value input, option value			$ 9.68
[1]	udited, in thousands, except per unit amounts) Three months ended March 31, 2017 2016Revenue: Commodity sales$158,501 $107,570Services41,388 36,044 Gain (loss) on commodity derivatives, net(257) (238)Total revenue199,632143,376Operating expenses: Costs of sales132,785 73,938Direct operating expenses30,088 30,575Corporate expenses32,844 21,101Depreciation, amortization and accretion expense29,351 25,041(Gain) loss on sale of assets, net(228) 1,122Total operating expenses224,840151,777Operating loss(25,208)(8,401)Other income (expense), net Interest expense(17,966) (8,302)Other income (expense)14 31Earnings in unconsolidated affiliates15,402 7,343Loss from continuing operations before taxes(27,758)(9,329)Income tax expense(1,123) (735)Loss from continuing operations(28,881)(10,064)Loss from discontinued operations, net of tax— (539)Net loss(28,881)(10,603)Less: Net income (loss) attributable to noncontrolling interests1,303 (3)Net loss attributable to the Partnership$(30,184)$(10,600) General Partner’s interest in net loss$(420) $(97)Limited Partners’ interest in net loss$(29,764) $(10,503) Distribution declared per common unit (1)$0.4125 $0.4725Limited Partners’ net loss per common unit (See Note 14): Basic and diluted: Loss from continuing operations$(0.75) $(0.32)Loss from discontinued operations— (0.01)Net loss$(0.75)$(0.33)Weighted average number of common units outstanding:Basic and diluted51,451 50,925(1) Declared and paid

Partners_ Capital Distributions

Partners’ Capital Distributions (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Limited Partner [Member]
Class of Stock [Line Items]
General partner's distribution	$ 33,685	$ 31,412
General Partner [Member]
Class of Stock [Line Items]
General partner's distribution	282	2,087
Paid In-kind Unit [Member]
Class of Stock [Line Items]
General partner's distribution	2,733	4,380
Paid In-kind Unit [Member] | Series A [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	2,733	4,380
Paid [Member] | Paid / Accrued [Member]
Class of Stock [Line Items]
General partner's distribution	32,198	29,028
Paid [Member] | Paid / Accrued [Member] | Limited Partner [Member]
Class of Stock [Line Items]
General partner's distribution	24,915	27,000
Paid [Member] | Paid / Accrued [Member] | General Partner [Member]
Class of Stock [Line Items]
General partner's distribution	167	2,028
Paid [Member] | Paid / Accrued [Member] | Series A [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	2,527	0
Paid [Member] | Paid / Accrued [Member] | Series C [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	3,627	0
Paid [Member] | Paid / Accrued [Member] | Series D [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	962	0
Accrued [Member] | General Partner [Member]
Class of Stock [Line Items]
General partner's distribution	200	2,028
Accrued [Member] | Paid / Accrued [Member]
Class of Stock [Line Items]
General partner's distribution	8,885	4,471
Accrued [Member] | Paid / Accrued [Member] | Series A [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	4,296	4,471
Accrued [Member] | Paid / Accrued [Member] | Series C [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	3,627	0
Accrued [Member] | Paid / Accrued [Member] | Series D [Member] | Preferred Partner [Member]
Class of Stock [Line Items]
General partner's distribution	$ 962	$ 0

Net Income (Loss) per Limited70

Net Income (Loss) per Limited Partner Unit Net Income (Loss) per Limited Partner Unit (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net loss	$ (28,881)	$ (10,064)
Less: Net income (loss) attributable to noncontrolling interests	1,303	(3)
Net income (loss) from continuing operations attributable to the Partnership	(30,184)	(10,061)
Distributions	4,296	4,471
General partner’s share in undistributed loss	(560)	(418)
Net loss from continuing operations available to Limited Partners	(38,709)	(16,142)
Net loss from discontinued operations available to Limited Partners	0	(539)
Net loss available to Limited Partners	$ (38,709)	$ (16,681)
Weighted average number of common units outstanding: basic and diluted (shares)	51,451	50,925
Limited Partners' net loss per common unit (in usd per share)	$ (0.75)	$ (0.33)
Series C [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Distributions	$ 3,627	$ 0
Series D [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Distributions	962	0
General Partner [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
General partner's distribution	282	2,087
General Partner [Member] | Accrued [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
General partner's distribution	$ 200	$ 2,028

Long Term Incentive Plan (Detai

Long Term Incentive Plan (Details Textual) - Long Term Incentive Plan [Member] - USD ($) $ in Millions	Nov. 19, 2015	Dec. 31, 2015	Mar. 31, 2017	Mar. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Additional number of common units authorized for issuance (shares)	6,000,000
Equity compensation expense				$ 1.6
Equity instruments other than options, vested in period, fair value			$ 5	$ 0.9
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
Minimum [Member] | Phantom Share Units (PSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period			3 years
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]	3 Months Ended
	Mar. 31, 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	1,558,834.89
Granted (in shares) | shares	2,000
Forfeited (in shares) | shares	(964)
Vested (in shares) | shares	(319,572)
Outstanding at end of period (in shares) | shares	1,240,299
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	30.14
Vested (in usd per share) | $ / shares	7.41
Outstanding at end of period (in usd per share) | $ / shares	$ 6.86

Commitments and Contingencies (

Commitments and Contingencies (Details) $ in Millions	Mar. 31, 2017USD ($)
Employee Severance [Member] | Merger-related costs
Other Commitments [Line Items]
Obligation fair value	$ 3.4

Related Party Transactions (De

Related Party Transactions (Details Textual) $ in Thousands	3 Months Ended
	Mar. 31, 2017USD ($)quarter	Mar. 31, 2016USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2013USD ($)
Related Party Transaction [Line Items]
Direct operating expenses	$ 30,088	$ 30,575
Direct operating expenses	32,844	21,101
Blackwater [Member]
Related Party Transaction [Line Items]
Additional consideration					$ 5,000
Additional Blackwater acquisition consideration	5,000
General Partner [Member]
Related Party Transaction [Line Items]
Maximum financial support	$ 25,000
Term of maximum financial support (Number of Quarters) | quarter	8
Related Party Transaction, Costs Absorbed by Related Party	$ 9,600
Receivable balance from affiliate		1,500
Direct operating expenses	4,000	2,500
Republic Midstream, LLC (“Republic”) [Member]
Related Party Transaction [Line Items]
Monthly fee	100
Revenue from related parties	300	300
Receivable balance from affiliate	1,400
Affiliated Entity [Member]
Related Party Transaction [Line Items]
Management fees revenue	600
J P Energy Development L P [Member]
Related Party Transaction [Line Items]
Net receivable from JP Development				$ 7,900
Other Current Liabilities [Member] | General Partner [Member]
Related Party Transaction [Line Items]
Related party transaction, due to related party	$ 1,300		$ 3,900
American Panther [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Ownership interest in subsidiary (percent)	60.00%
American Panther [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Direct operating expenses	$ 800	300
Direct operating expenses	400	100
CIMA Energy Ltd [Member] | Vice President [Member]
Related Party Transaction [Line Items]
Revenue from related parties	700	900
Purchases from related party	$ 1,400	1,000
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

Reportable Segments - Reconcili

Reportable Segments - Reconciliation of Gross Profit (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Segment Reporting Information [Line Items]
Depreciation, amortization and accretion expense	$ 29,351	$ 25,252
Segment gross margin	80,104	74,045
Direct operating expenses	30,088	30,575
Total Operating Margin	(25,208)	(8,401)
Gain (loss) on commodity derivatives, net	(257)	(238)
Corporate expenses	32,844	21,101
Depreciation, amortization and accretion expense	29,351	25,041
(Gain) loss on sale of assets, net	(228)	1,122
Interest expense	17,966	8,302
Other income	(14)	(31)
Other, net	671	(365)
Income tax expense	1,123	735
Loss from discontinued operations, net of tax	0	539
Less: Net income (loss) attributable to noncontrolling interests	1,303	(3)
Net loss attributable to the Partnership	(30,184)	(10,600)
Gathering and Processing reporting segment [Member]
Segment Reporting Information [Line Items]
Segment gross margin	11,251	11,619
Direct operating expenses	8,065	8,548
Gain (loss) on commodity derivatives, net	(7)	(103)
Liquid Pipelines and Services [Member]
Segment Reporting Information [Line Items]
Segment gross margin	6,470	5,850
Direct operating expenses	2,074	2,467
Gain (loss) on commodity derivatives, net	372	(233)
Natural Gas Transportation Services [Member]
Segment Reporting Information [Line Items]
Segment gross margin	6,119	5,563
Direct operating expenses	1,235	1,227
Gain (loss) on commodity derivatives, net	0	0
Offshore Pipelines and Services [Member]
Segment Reporting Information [Line Items]
Segment gross margin	25,802	13,265
Direct operating expenses	2,579	2,253
Gain (loss) on commodity derivatives, net	0	0
Terminalling Services [Member]
Segment Reporting Information [Line Items]
Segment gross margin	11,160	9,443
Direct operating expenses	3,073	2,609
Gain (loss) on commodity derivatives, net	0	(175)
Propane Marketing Services [Member]
Segment Reporting Information [Line Items]
Segment gross margin	19,302	28,305
Direct operating expenses	13,062	13,471
Gain (loss) on commodity derivatives, net	(622)	273
All Operating Segments, Excluding Terminalling Segment [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	27,015	27,966
Segment Reconciling Items [Member]
Segment Reporting Information [Line Items]
Total Operating Margin	$ 53,089	$ 46,079

Reportable Segments (Details)

Reportable Segments (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Segment Reporting, Revenue Reconciling Item [Line Items]
Depreciation, amortization and accretion expense	$ 29,351	$ 25,252
Segment information
Revenue	199,889	143,614
Gain (loss) on commodity derivatives, net	(257)	(238)
Total revenue	199,632	143,376
Earnings in unconsolidated affiliates	15,402	7,343
Cost of Sales	132,785	73,938
Direct operating expenses	30,088	30,575
Corporate expenses	32,844	21,101
Depreciation, amortization and accretion expense	29,351	25,041
(Gain) loss on sale of assets, net	(228)	1,122
Total operating expenses	224,840	151,777
Interest expense	17,966	8,302
Other (income) expense	(14)	(31)
Loss from continuing operations before taxes	(27,758)	(9,329)
Income tax expense	1,123	735
Income (loss from continuing operation	(28,881)	(10,064)
Loss from discontinued operations, net of tax	0	539
Net loss	(28,881)	(10,603)
Less: Net income (loss) attributable to noncontrolling interests	1,303	(3)
Net loss attributable to the Partnership	(30,184)	(10,600)
Segment gross margin	80,104	74,045
Gathering and Processing reporting segment [Member]
Segment information
Revenue	34,407	23,295
Gain (loss) on commodity derivatives, net	(7)	(103)
Total revenue	34,400	23,192
Earnings in unconsolidated affiliates	0	0
Cost of Sales	23,187	11,707
Direct operating expenses	8,065	8,548
Segment gross margin	11,251	11,619
Liquid Pipelines and Services [Member]
Segment information
Revenue	82,039	44,515
Gain (loss) on commodity derivatives, net	372	(233)
Total revenue	82,411	44,282
Earnings in unconsolidated affiliates	1,088	0
Cost of Sales	77,077	38,654
Direct operating expenses	2,074	2,467
Segment gross margin	6,470	5,850
Natural Gas Transportation Services [Member]
Segment information
Revenue	12,438	9,795
Gain (loss) on commodity derivatives, net	0	0
Total revenue	12,438	9,795
Earnings in unconsolidated affiliates	0	0
Cost of Sales	6,260	4,224
Direct operating expenses	1,235	1,227
Segment gross margin	6,119	5,563
Offshore Pipelines and Services [Member]
Segment information
Revenue	14,831	7,003
Gain (loss) on commodity derivatives, net	0	0
Total revenue	14,831	7,003
Earnings in unconsolidated affiliates	14,314	7,343
Cost of Sales	3,343	1,081
Direct operating expenses	2,579	2,253
Segment gross margin	25,802	13,265
Terminalling Services [Member]
Segment information
Revenue	18,626	14,393
Gain (loss) on commodity derivatives, net	0	(175)
Total revenue	18,626	14,218
Earnings in unconsolidated affiliates	0	0
Cost of Sales	4,393	2,205
Direct operating expenses	3,073	2,609
Segment gross margin	11,160	9,443
Propane Marketing Services [Member]
Segment information
Revenue	37,548	44,613
Gain (loss) on commodity derivatives, net	(622)	273
Total revenue	36,926	44,886
Earnings in unconsolidated affiliates	0	0
Cost of Sales	18,525	16,067
Direct operating expenses	13,062	13,471
Segment gross margin	19,302	28,305
Commodity Contract [Member]
Segment information
Gain (loss) on commodity derivatives, net	377	(607)
Gain (Loss) on Derivative Instruments [Member] | Commodity Contract [Member]
Segment information
Gain (loss) on commodity derivatives, net	$ 699	$ (388)

Reportable Segments Reportable

Reportable Segments Reportable Segments - Assets (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Assets	$ 2,046,243	$ 2,349,321
Gathering and Processing reporting segment [Member]
Segment Reporting Information [Line Items]
Assets	390,334	532,009
Liquid Pipelines and Services [Member]
Segment Reporting Information [Line Items]
Assets	447,121	422,636
Offshore Pipelines and Services [Member]
Segment Reporting Information [Line Items]
Assets	365,507	385,893
Natural Gas Transportation Services [Member]
Segment Reporting Information [Line Items]
Assets	176,740	221,604
Terminalling Services [Member]
Segment Reporting Information [Line Items]
Assets	277,632	299,534
Propane Marketing Services [Member]
Segment Reporting Information [Line Items]
Assets	134,604	140,864
Other Segments [Member]
Segment Reporting Information [Line Items]
Assets	$ 254,305	$ 346,781

Reportable Segments (Details Te

Reportable Segments (Details Textual) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Segment Reporting Information [Line Items]
Direct operating expenses	$ 30,088	$ 30,575
Gathering and Processing reporting segment [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	8,065	8,548
Liquid Pipelines and Services [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	2,074	2,467
Natural Gas Transportation Services [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	1,235	1,227
Offshore Pipelines and Services [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	2,579	2,253
Propane Marketing Services [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	13,062	13,471
Terminalling Services [Member]
Segment Reporting Information [Line Items]
Direct operating expenses	$ 3,073	$ 2,609

Subsequent Event (Details)

Subsequent Event (Details) - $ / shares		Apr. 25, 2017	Mar. 31, 2017	Mar. 31, 2016
Subsequent Event [Line Items]
Distribution declared per common unit (in usd per share)	[1]		$ 0.4125	$ 0.4725
Subsequent Event [Member]
Subsequent Event [Line Items]
Distribution declared per common unit (in usd per share)		$ 0.4125
Distribution made to limited partner, distributions declared, per unit, annualized basis (in usd per share)		$ 1.65
[1]	udited, in thousands, except per unit amounts) Three months ended March 31, 2017 2016Revenue: Commodity sales$158,501 $107,570Services41,388 36,044 Gain (loss) on commodity derivatives, net(257) (238)Total revenue199,632143,376Operating expenses: Costs of sales132,785 73,938Direct operating expenses30,088 30,575Corporate expenses32,844 21,101Depreciation, amortization and accretion expense29,351 25,041(Gain) loss on sale of assets, net(228) 1,122Total operating expenses224,840151,777Operating loss(25,208)(8,401)Other income (expense), net Interest expense(17,966) (8,302)Other income (expense)14 31Earnings in unconsolidated affiliates15,402 7,343Loss from continuing operations before taxes(27,758)(9,329)Income tax expense(1,123) (735)Loss from continuing operations(28,881)(10,064)Loss from discontinued operations, net of tax— (539)Net loss(28,881)(10,603)Less: Net income (loss) attributable to noncontrolling interests1,303 (3)Net loss attributable to the Partnership$(30,184)$(10,600) General Partner’s interest in net loss$(420) $(97)Limited Partners’ interest in net loss$(29,764) $(10,503) Distribution declared per common unit (1)$0.4125 $0.4725Limited Partners’ net loss per common unit (See Note 14): Basic and diluted: Loss from continuing operations$(0.75) $(0.32)Loss from discontinued operations— (0.01)Net loss$(0.75)$(0.33)Weighted average number of common units outstanding:Basic and diluted51,451 50,925(1) Declared and paid

Supplemental Cash Flow Inform80

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Supplemental Cash Flow Elements [Abstract]
Increase (decrease) in accrued property, plant and equipment purchases	$ (1,371)	$ 1,876
Contributions	4,000	2,500
Accrued cash distributions on convertible preferred units	8,885	4,471
Paid-in-kind distributions on convertible preferred units	2,733	4,380
Cancellation of escrow units	$ 0	$ 6,817