Third Coast Midstream (AMID) 10-Q 14 Aug 18 2018 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2018	Aug. 06, 2018
Document Information [Line Items]
Entity Registrant Name	American Midstream Partners, LP
Entity Central Index Key	1,513,965
Document Type	10-Q
Document Period End Date	Jun. 30, 2018
Amendment Flag	false
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding (in shares)		52,981,070
Series A
Document Information [Line Items]
Entity Common Stock, Shares Outstanding (in shares)		11,009,729
Series C
Document Information [Line Items]
Entity Common Stock, Shares Outstanding (in shares)		9,241,642

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Current assets
Cash and cash equivalents	$ 17,037	$ 8,782
Restricted cash	24,541	20,352
Accounts receivable, net of allowance for doubtful accounts of $372 and $225 as of June 30, 2018 and December 31, 2017, respectively	88,352	98,132
Inventory	2,661	2,966
Other current assets	30,570	23,420
Total current assets	163,161	153,652
Property, plant and equipment, net	992,659	1,095,585
Goodwill	51,723	128,866
Restricted cash-long term	5,058	5,045
Intangible assets, net	139,083	174,010
Investments in unconsolidated affiliates	331,530	348,434
Other assets, net	27,984	17,874
Assets held for sale	230,129	0
Total assets	1,941,327	1,923,466
Current liabilities
Accounts payable	53,093	41,102
Accrued gas and crude oil purchases	15,862	19,986
Accrued expenses and other current liabilities	67,395	68,854
Current portion of long-term debt	3,624	7,551
Total current liabilities	139,974	137,493
Asset retirement obligations	67,358	66,194
Other long-term liabilities	15,426	2,080
Long-term debt	1,278,062	1,201,456
Deferred tax liability	8,628	8,123
Liabilities held for sale	2,237	0
Total liabilities	1,511,685	1,415,346
Commitments and contingencies (Note 18)
Convertible preferred units	317,180	317,180
Equity and partners’ capital
General Partner interests (965 and 965 units issued and outstanding as of June 30, 2018 and December 31, 2017, respectively)	(76,307)	(96,552)
Limited Partner interests (52,972 and 52,711 units issued and outstanding as of June 30, 2018 and December 31, 2017, respectively)	175,003	273,703
Accumulated other comprehensive income	23	28
Total partners’ capital	98,719	177,179
Noncontrolling interests	13,743	13,761
Total equity and partners’ capital	112,462	190,940
Total liabilities, equity and partners’ capital	$ 1,941,327	$ 1,923,466

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) shares in Thousands, $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Allowance for doubtful accounts receivable	$ 372	$ 225
General partner interest, units issued (in shares)	965	965
General partner interest units, outstanding (in shares)	965	965
Preferred, units, issued (in shares)	52,972	52,711
Preferred, units, outstanding (in shares)	52,972	52,711

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Revenue:
Commodity sales	$ 164,737	$ 124,476	$ 323,599	$ 247,997
Services	55,835	37,355	102,741	77,547
Gain on commodity derivatives, net	(355)	199	(296)	564
Total revenue	220,217	162,030	426,044	326,108
Operating expenses:
Costs of sales	161,508	115,020	311,674	230,488
Direct operating expenses	21,742	18,709	45,189	36,114
Corporate expenses	23,372	27,374	46,064	57,487
Depreciation, amortization and accretion	21,236	26,483	43,234	52,053
Gain on sale of assets, net	0	18	(95)	(3)
Total operating expenses	227,858	187,604	446,066	376,139
Operating loss	(7,641)	(25,574)	(20,022)	(50,031)
Other income (expense), net
Interest expense, net of capitalized interest	(19,691)	(17,122)	(33,567)	(35,078)
Other income (expense), net	169	0	191	(37)
Earnings in unconsolidated affiliates	10,446	17,552	23,119	32,954
Loss from continuing operations before income taxes	(16,717)	(25,144)	(30,279)	(52,192)
Income tax expense	(557)	(757)	(837)	(1,880)
Loss from continuing operations	(17,274)	(25,901)	(31,116)	(54,072)
Loss from discontinued operations	0	(1,801)	0	(2,511)
Net loss	(17,274)	(27,702)	(31,116)	(56,583)
Less: Net income attributable to noncontrolling interests	13	1,462	57	2,765
Net loss attributable to the Partnership	(17,287)	(29,164)	(31,173)	(59,348)
General Partner’s interest in net loss	(225)	(375)	(405)	(795)
Limited Partners’ interest in net loss	$ (17,062)	$ (28,789)	$ (30,768)	$ (58,553)
Distribution declared per common unit (in usd per share)	$ 0.1031	$ 0.4125	$ 0.5156	$ 0.8250
Limited Partners’ net income (loss) per common unit, basic and diluted:
Income (loss) from continuing operations (in usd per share)	(0.48)	(0.69)	(0.89)	(1.41)
Income (loss) from discontinued operations (in usd per share)	0	(0.03)	0	(0.05)
Net income (loss) (in usd per share)	$ (0.48)	$ (0.72)	$ (0.89)	$ (1.46)
Weighted average number of common units outstanding:
Weighted average number of common units outstanding: basic and diluted (shares)	52,969	51,870	52,869	51,870

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Comprehensive Loss (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Statement of Comprehensive Income [Abstract]
Net loss	$ (17,274)	$ (27,702)	$ (31,116)	$ (56,583)
Unrealized gain (loss) related to postretirement benefit plan	11	24	(5)	42
Comprehensive loss	(17,263)	(27,678)	(31,121)	(56,541)
Less: Comprehensive income attributable to noncontrolling interests	13	1,462		2,765
Comprehensive loss attributable to the Partnership	$ (17,276)	$ (29,140)	$ (31,178)	$ (59,306)

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Changes in Partners' Capital and Noncontrolling Interests - USD ($) $ in Thousands	Total	Panther Asset Management LLC (Panther) [Member]	Parent [Member]	Parent [Member]Panther Asset Management LLC (Panther) [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interest [Member]	General Partner	General PartnerPanther Asset Management LLC (Panther) [Member]	Limited Partner [Member]
Partners' Capital at Dec. 31, 2016	$ 585,157		$ 568,402		$ (40)	$ 16,755	$ (47,645)		$ 616,087
Increase (Decrease) in Partners' Capital [Roll Forward]
Net (loss) income	(56,583)		(59,348)			2,765	(795)		(58,553)
Contributions	27,130		27,130				23,130		4,000
Distributions	(64,168)		(64,168)				(594)		(63,574)
Distributions to NCI owners	(1,795)					(1,795)
Contributions from NCI owners	296					296
LTIP vesting							(4,633)		4,633
Tax netting repurchase	(1,642)		(1,642)						(1,642)
Equity compensation expense	5,233		5,233				3,873		1,360
Post-retirement benefit plan	42		42		42
Partners' Capital at Jun. 30, 2017	493,670		475,649		2	18,021	(26,664)		502,311
Partners' Capital at Dec. 31, 2017	190,940		177,179		28	13,761	(96,552)		273,703
Cumulative effect of accounting change (Note 3) at Dec. 31, 2017	(10,691)		(10,691)				(139)		(10,552)
Increase (Decrease) in Partners' Capital [Roll Forward]
Net (loss) income	(31,116)		(31,173)			57	(405)		(30,768)
Contributions	23,264		23,264				23,264		0
Distributions	(60,883)		(60,883)				(795)		(60,088)
Distributions to NCI owners	(75)					(75)
Distribution for acquisition of Trans-Union		$ (38)		$ (38)				$ (38)
LTIP vesting							(3,836)		3,836
Tax netting repurchase	(1,128)		(1,128)						(1,128)
Equity compensation expense	2,194		2,194				2,194
Post-retirement benefit plan	(5)		(5)		(5)
Partners' Capital at Jun. 30, 2018	$ 112,462		$ 98,719		$ 23	$ 13,743	$ (76,307)		$ 175,003

Condensed Consolidated Stateme7

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Cash flows from operating activities
Net loss	$ (31,116)	$ (56,583)
Adjustments to reconcile net loss to net cash provided by operating activities including discontinued operations:
Depreciation, amortization and accretion	43,234	59,521
Amortization of debt issuance costs	2,649	2,456
Amortization of weather derivative premium	550	475
Unrealized (gain) loss on derivatives contracts, net	(5,851)	3,020
Non-cash compensation expense	2,194	5,233
(Gain) loss on sale of assets and business, net of transaction costs of $2.5 million (Note 4)	(95)	(176)
Corporate overhead support	0	4,000
Other non-cash items	(22)	1,906
Earnings in unconsolidated affiliates	(23,119)	(32,954)
Distributions from unconsolidated affiliates	21,404	32,954
Deferred tax expense	505	1,250
Bad debt expense	406	515
Changes in operating assets and liabilities, net of effects of acquisitions:
Accounts receivable	5,019	8,761
Inventory	(519)	(1,738)
Risk management assets and liabilities	(989)	(1,157)
Other current assets	(4,640)	(6,447)
Other assets, net	(3,565)	147
Accounts payable	13,858	(12,069)
Accrued gas and crude oil purchases	(4,052)	6,320
Accrued expenses and other current liabilities	(6,903)	13,216
Asset retirement obligations	(7)	(45)
Other liabilities	19	(247)
Net cash provided by operating activities	8,960	28,358
Cash flows from investing activities
Acquisitions, net of cash acquired and settlements	0	(32,000)
Contributions to unconsolidated affiliates	(2,946)	0
Additions to property, plant and equipment and other	(56,533)	(44,039)
Proceeds from disposals of property, plant and equipment	8	121
Insurance proceeds from involuntary conversion of property, plant and equipment	0	150
Distributions from unconsolidated affiliates, return of capital	23,150	5,440
Net cash used in investing activities	(36,321)	(70,328)
Cash flows from financing activities
Contributions	23,264	23,130
Distributions	(52,529)	(60,494)
Contribution from noncontrolling interest owners	0	296
Distributions to noncontrolling interests owners	(75)	(1,795)
LTIP tax netting unit repurchase	(1,128)	(1,642)
Payment of debt issuance costs	(2,742)	(2,116)
Payments of other debt	(4,316)	(3,447)
Payments of credit agreement	(187,200)	(383,908)
Borrowings on credit agreement	265,600	173,700
Other	830	0
Net cash provided by (used in) financing activities	40,182	(257,354)
Net increase (decrease) in cash, cash equivalents, and restricted cash	12,821	(299,324)
Cash, Cash equivalents and Restricted cash
Beginning of period	34,179	329,230
Cash and cash equivalents	17,037	5,903
Cash included in assets held for sale	364	0
Restricted cash - current	24,541	18,965
Restricted cash - non-current	5,058	5,038
End of period	47,000	29,906
Long-term Debt | Senior Notes
Cash flows from financing activities
Payment of long-term debt and 3.97% Senior Notes	(644)	(1,078)
3.97% Trans-Union Secured Senior notes | Senior Notes
Cash flows from financing activities
Payment of long-term debt and 3.97% Senior Notes	$ (878)	$ 0

Condensed Consolidated Stateme8

Condensed Consolidated Statements of Cash Flows (Parentheticals)	Jun. 30, 2018	Dec. 31, 2017
3.97% Trans-Union Secured Senior notes | Senior Notes
Debt instrument, stated interest rate (percent)	3.97%	3.97%

Organization and Basis of Prese

Organization and Basis of Presentation	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation	(1) Organization and Basis of Presentation Organization American Midstream Partners, LP (together with its consolidated subsidiaries, the “Partnership”, “we”, “us”, or “our”) is a growth-oriented Delaware limited partnership that was formed in August 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 77.0% directly owned by High Point Infrastructure Partners, LLC (“HPIP”) and 23.0% indirectly owned by Magnolia Infrastructure Holdings, LLC (“Magnolia”), 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. We provide critical midstream infrastructure that links producers of natural gas, crude oil, NGLs, condensate and specialty chemicals to numerous intermediate and end-use markets. Through our five reportable segments, (1) Gas Gathering and Processing Services, (2) Liquid Pipelines and Services, (3) Natural Gas Transportation Services, (4) Offshore Pipelines and Services, and (5) Terminalling Services, we engage in the business of gathering, treating, processing and transporting natural gas; gathering, transporting, storing, treating and fractionating NGLs; gathering, storing and transporting crude oil and condensates; and storing specialty chemical products 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. Basis of presentation The accompanying Condensed Consolidated Financial Statements are unaudited and have been prepared in accordance with Article 10 of Regulation S-X for interim financial information. Accordingly, they do not include all the information and notes required by GAAP for complete financial statements. In the opinion of our management, all adjustments, consisting only of normal recurring adjustments, considered necessary for a fair statement have been included. The results of operations for interim periods are not necessarily indicative of results of operations for a full year. These Condensed Consolidated Financial Statements should be read in conjunction with our Consolidated Financial Statements and Notes thereto included in our Annual Report on Form 10-K (“Annual Report”) for the year ended December 31, 2017 filed with the U.S. Securities and Exchange Commission (the “SEC”) on April 9, 2018 (the “2017 Form 10-K”). On April 15, 2013, ArcLight affiliates obtained control of our General Partner. We account for transactions between entities under common control at the affiliate's historical costs. For those transactions, our historical financial statements will be revised to include the results attributable to the assets acquired as if they were acquired on April 15, 2013 or the date the ArcLight affiliates obtained control of the assets or business acquired.

New Accounting Pronouncements

New Accounting Pronouncements	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
New Accounting Pronouncements	Recent Accounting Pronouncements and Critical Accounting Policies Standards Adopted in 2018 Revenue from Contracts with Customers (Topic 606 ) - In May 2014, the Financial Accounting Standards Board (the “FASB”) issued a new standard related to revenue recognition which supersedes most of the existing revenue recognition requirements in GAAP and requires entities to recognize revenue at an amount that reflects the consideration to which an entity expects to be entitled in exchange for transferring goods or services to a customer. It also requires significantly expanded disclosures regarding the qualitative and quantitative information of an entity’s nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The FASB has issued several amendments to the standard, including clarification on accounting for licenses of intellectual property, identifying performance obligations, reporting gross versus net revenue and narrow-scope revisions and practical expedients. We adopted the new standard on January 1, 2018 (the “initial application” date): • using the modified retrospective application, with no restatement of the comparative periods presented and a cumulative effect adjustment to retained earnings as of the date of adoption; and • disclosing the impact of the new standard in our Condensed Consolidated Financial Statements included in this report. Our revenue is derived from the provision of gathering, processing, transportation, terminalling and storage services and the sale of commodities primarily to marketers and brokers, refiners and chemical manufacturers, utilities and power generation customers, industrial users, and local distribution companies. Beginning on January 1, 2018, we account for revenue from contracts with customers in accordance with Topic 606. The unit of account in Topic 606 is a performance obligation, which is a promise in a contract to transfer to a customer either a distinct good or service (or bundle of goods or services) or a series of distinct goods or services provided at a point in time or over a period of time. Topic 606 requires that a contract’s transaction price, which is the amount of consideration to which an entity expects to be entitled in exchange for transferring promised goods or services to a customer, is to be allocated to each performance obligation in the contract based on relative standalone selling prices and recognized as revenue when (point in time) or as (over time) the performance obligation is satisfied. Commodity Sales - For the majority of our commodity sales contracts: (i) each unit of product is a separate performance obligation, since our promise is to sell multiple distinct units of product at a point in time; (ii) the transaction price principally consists of variable consideration, which is determinable on commodity index prices for the volume of the product sold to the customer that month; and (iii) the transaction price is allocated to each performance obligation based on the product’s standalone selling price. Revenues from sales of commodities are recognized at the point in time when control of the commodity transfers to the customer, which generally occurs upon delivery of the product to the customer or its designee. Payment is generally received from the customer in the month following delivery. Contracts with customers have varying terms, including spot sales, month-to-month contracts and multi-year agreements. In our Liquid Pipelines and Services segment, we enter into purchase and sales contracts as well as buy/sell contracts with counterparties, under which we gather and transport different types of crude oil and eventually sell the crude oil to either the same counterparty or different counterparties. For each of these arrangements, the Partnership assesses if control of the underlying commodity volumes transfer to the Partnership. Generally, the Partnership is unable to direct the use of the commodity volumes it purchases from the supplier because the Partnership is contractually required to redeliver an equivalent volume of the commodity back to the supplier or to a specified customer therefore, these arrangements are recorded on a net basis. Occasionally, we enter into crude oil inventory exchange arrangements with the same counterparty where the purchase and sale of inventory are considered in contemplation of each other. These types of arrangements are accounted for as inventory exchanges and are recorded on a net basis. Services - The Partnership provides gathering, processing, transportation, terminalling and storage services pursuant to a variety of contracts. Generally, for the majority of these contracts: (i) our promise is to transfer (or stand ready to transfer) a series of distinct integrated services over a period of time, which is a single performance obligation and (ii) the transaction price includes fixed or variable consideration, or both fixed and variable consideration. The amount of consideration is determinable at contract inception or at each month’s end based on our right to invoice at month end for the value of services provided to the customer in that month. Revenue is recognized over the service period specified in the contract as the services are rendered using a time-based (passage of time) or units-based (units of service transferred) method for measuring provision of the services. Progress towards satisfying our performance obligation is based on the firm or interruptible nature of the promised service and the terms and conditions of the contract (such as contracts with or without makeup rights). Payment is generally received from the customer in the month of service or the month following the service. Contracts with customers generally are a combination of month-to-month and multi-year agreements. Firm Services - Firm services are services that are promised to be available to the customer at all times during the term of the contract, with limited exceptions. These agreements require customers to deliver, transport or throughput a minimum volume over an agreed upon period. Substantially all of such agreements are entered into with customers to economically support the return on our capital expenditure necessary to construct the related asset. Our firm service contracts are typically structured with take-or-pay or minimum volume provisions, which specify minimum service quantities a customer will pay for even if it chooses not to receive or use them in the specified service period (referred to as “deficiency quantities”). Under firm service contracts, we record a receivable from the customer in the period that services are provided or when the transaction occurs, including amounts for deficiency quantities from customers associated with minimum volume commitments. If a customer has a make-up right associated with a deficiency, we defer the revenue attributable to the counterparty’s make-up right and subsequently recognize the revenue at the earlier of when the deficiency volume is delivered or shipped, when the make-up right expires or when it is determined that the customer’s ability to utilize the make-up right is remote. Interruptible Services - Interruptible services are services provided to the extent that we have available capacity. Generally, we do not have an obligation to perform these services until we accept a customer’s periodic request for service. For the majority of these contracts, the customer will pay only for the actual quantities of services it chooses to receive or use, and we typically recognize the transaction price as revenue as those units of service are transferred to the customer in the specified service period. Gathering and Processing - 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. Services can be firm if subject to a minimum volume commitment or acreage dedication or interruptible when offered on an as requested, non-guaranteed basis. Revenue for fee-based gathering and processing services are valued based on the rate in effect for the month of service and is recognized in the month of service based on the volumes of natural gas we gather, process and fractionate. Under these arrangements, we may take control of: (i) none of the commodities we sell (i.e., residue gas or NGLs), (ii) a portion of the commodities we sell, or (iii) all of the commodities we sell. In those instances where we purchase and obtain control of the entire natural gas stream in our producer arrangements, we have determined these are contracts with suppliers rather than contracts with customers and therefore, these arrangements are not included in the scope of Topic 606. These supplier arrangements are subject to updated guidance in Accounting Standards Codification (“ASC”) 705, “ Cost of Sales and Services ,” whereby any embedded fees within such contracts, which historically have been reported as services revenue, are now reported as a reduction to cost of sales upon adoption of Topic 606. In those instances where we remit all of the cash proceeds received from third parties for selling the extracted commodities to the producer, less the fees attributable to these arrangements, we have determined that the producer has control over these commodities. Upon adoption of Topic 606, we eliminated recording both sales revenue (natural gas and products) and cost of sales amounts and now only record fees attributable to these arrangements as service revenues. In other instances where we do not obtain control of the extracted commodities we sell, we are acting as an agent for the producer and, upon adoption of Topic 606, we have continued to recognize services revenue for the net amount of consideration we retain in exchange for our service. The Partnership may charge additional service fees to customers for a portion of the contract term (i.e., for the first year of a contract or until reaching a volume threshold) due to the significant upfront capital investment, and these fees are initially deferred and recognized to revenue over the expected period of customer benefit, generally the lesser of the expected contract term or the life of the related properties. Transportation - Our transportation operations generally consist of fee-based activities associated with transporting crude oil, natural gas, and NGL on pipelines, gathering systems and trucks. Revenues from pipeline tariffs and fees are associated with the transportation at a published tariff, as well as revenues associated with agreements for committed capacity on various assets. We primarily recognize pipeline tariff and fee revenues over time based on the volumes delivered and invoiced. The majority of our pipeline tariff and fee revenues are based on actual volumes and rates. As is common in the pipeline transportation industry, our tariffs incorporate a loss allowance factor. The intent of the allowance in arrangements for the transportation of natural gas is to approximate the natural shrink that occurs when transporting the gas. For crude oil transportation arrangements, loss allowance provisions are immaterial to the Partnership. In the event the Partnership retains excess natural gas and crude oil and subsequently sells the commodity to a third party, the sale is recorded at that point in time as a commodity sale. Terminalling and Storage - In our Terminalling Services segment, we generally receive fee-based compensation on guaranteed firm storage contracts, throughput fees charged to our customers when their products are either received or disbursed, and other operational charges associated with ancillary services provided to our customers, such as excess throughput, steam heating and truck weighing at our marine terminals. Storage fees resulting from short-term and long-term contracts are typically recognized in revenue ratably over the term of the contract regardless of the actual storage capacity utilized. Adoption of the new revenue standard resulted in changes to the timing of revenue recognition and in the reclassification between financial statement line items. See Note 3 - Revenue Recognition , for further discussion . Statement of Cash Flows - In August 2016, the FASB issued Accounting Standards Update (“ASU”) No. 2016-15, “ Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments ” (“ASU 2016-15”). ASU 2016-15 provides specific guidance on cash flow classification issues to reduce diversity in practice. There was no impact of the retrospective adoption of this ASU on the Partnership’s Condensed Consolidated Statements of Cash Flows. In November 2016, the FASB issued ASU No. 2016-18, “ Statement of Cash Flows (Topic 230): Restricted Cash ”(“ASU 2016-18”), which requires amounts described as restricted cash and restricted cash equivalents to be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. A reconciliation between the balance sheet and the statement of cash flows must be disclosed when the balance sheet includes more than one-line item for cash, cash equivalents, restricted cash and restricted cash equivalents. We retrospectively adopted ASU 2016-15 and ASU 2016-18 as of January 1, 2018. Previously reported financial statements have been adjusted to reflect the above changes, as follows (in thousands): Six months ended June 30, 2017 Condensed Consolidated Statements of Cash Flows As Previously Reported Effect of Adoption As Adjusted Cash flows from operating activities Net loss $ (56,583 ) $ — $ (56,583 ) Adjustments to reconcile net loss to net cash provided by operating activities including discontinued operations 78,200 — 78,200 Restricted cash, short-term (3,135 ) (1 ) 3,135 (1 ) — Changes in operating assets and liabilities, net of effects of assets acquired and liabilities assumed (excluding restricted cash) 6,794 (1 ) (53 ) (1 ) 6,741 Net cash provided by (used in) operating activities 25,276 3,082 28,358 Cash flows from investing activities Restricted cash 302,643 (1 ) (302,643 ) (1 ) — Other investing activities (excluding restricted cash) (70,328 ) — (70,328 ) Net cash provided by (used in) investing activities 232,315 (302,643 ) (70,328 ) Cash flows from financing activities Other financing activities (257,354 ) — (257,354 ) Net cash used in financing activities (excluding restricted cash) (257,354 ) — (257,354 ) Net increase (decrease) in cash, cash equivalents, and restricted cash 237 (299,561 ) (299,324 ) Cash, cash equivalents and Restricted Cash Beginning of period 5,666 323,564 329,230 End of period $ 5,903 $ 24,003 $ 29,906 _____________________________________________ (1) ASU 2016-18 adjustment to move restricted cash to be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the condensed consolidated statement of cash flows. Stock Compensation - In May 2017, the FASB issued ASU No. 2017-09, “ Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting ” (“ASU 2017-09”). ASU 2017-09 was issued with the intent to clarify the scope of modification accounting and when it should be applied to a change to the terms or conditions of a share-based payment award. Under the new guidance, modification accounting is required for all changes to share based payment awards, unless all the following conditions are met: (i) there is no change to the fair value of the award, (ii) the vesting conditions have not changed, and (iii) the classification of the award as an equity instrument or a debt instrument has not changed. We adopted ASU 2017-09 on its effective date of January 1, 2018, and the adoption did not have a material impact on our Condensed Consolidated Financial Statements. Income Taxes - In March 2018, the FASB issued ASU No. 2018-05, “ Income Taxes (Topic 740): Amendments to SEC Paragraphs Pursuant to SEC Staff Accounting Bulletin No. 118 (SEC Update) ”(“ASU 2018-05”), to provide guidance for companies that have not completed their accounting for the income tax effects of the Tax Cuts and Jobs Act (the “Act”) in the period of enactment. The measurement period begins in the reporting period that includes the Act’s enactment date of December 22, 2017, and ends when a company has obtained, prepared and analyzed the information needed to complete the accounting requirements under ASU 2018-05 and should not extend beyond one year from the enactment date. The impact of adopting the new guidance on our consolidated financial position, cash flows or results of operations, as well as on related disclosures was not material. Standards Not Yet Adopted Leases (Topic 842) - In February 2016, the FASB issued ASU No. 2016-02 (“Topic 842”) “ Leases ”, which supersedes the lease recognition requirements in ASC Topic 840, “Leases”. Under the new guidance, for leases with a term longer than 12 months a lessee should recognize a lease liability and a right-of-use asset representing its right to use the underlying asset for the lease term. Topic 842 retains a classification distinction between finance leases and operating leases, with the classification affecting the pattern of expense recognition in the income statement. This ASU also requires enhanced disclosures. Early adoption is permitted. We are currently assessing the impact of this new guidance via review of existing contracts that may have a lease impact and other purchase obligations that contain embedded lease features, which are generally classified as operating leases under the existing guidance. We selected a third-party consulting firm to assist us with the adoption of the new guidance. We intend to complete any required changes to our systems, software applications and processes, including updating our internal controls during 2018. In 2018, the FASB also issued ASU No. 2018-01, “Land Easement Practical Expedient for Transition to Topic 842” and ASU No. 2018-11, “Targeted Improvements”. Under these updates, optional transition practical expedients are available i) whereby existing or expired land easements that were not previously accounted for as leases under Topic 840 are not required to be evaluated under Topic 842, and ii) lease and associated non-lease components are not required to be separated within a contract if certain criteria are met. In addition, under ASU No. 2018-11, companies may initially apply the new lease requirements at the effective date. We intend apply the new lease requirements as of January 1, 2019, recognizing a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption, and to apply the practical expedients. Financial Instruments - In June 2016, the FASB issued ASU No. 2016-13 (“ASU 2016-13”), “ Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments” . This guidance will become effective for interim and annual periods beginning after December 15, 2019. We expect to adopt ASU 2016-13 on January 1, 2020, and we are currently evaluating the effect that adopting this guidance will have on our consolidated financial position, results of operations and cash flows. Critical Accounting Policies and Estimates See Item 7 Section Critical Accounting Policies and Estimates and Item 1A. Risk Factors of the 2017 Form 10-K for additional information relating to our critical accounting policies and risk factors. Goodwill - We record goodwill for the excess of the cost of an acquisition over the fair value of the net assets of the acquired business. Goodwill is reviewed for impairment at least annually or more frequently if an event or change in circumstance indicates that an impairment may have occurred. We first assess qualitative factors to evaluate whether it is more likely than not that an impairment has occurred, and it is therefore necessary to perform the one-step quantitative goodwill impairment test. If the one-step quantitative goodwill impairment test indicates that the goodwill is impaired, an impairment loss is recorded, which is the difference between carrying value of the reporting unit and its fair value, with the impairment loss not to exceed the amount of goodwill recorded. When performing a quantitative impairment test, the Partnership generally determines the fair value of its reporting units using a discounted cash flow method. In the event the Partnership enters into an agreement to sell all or substantially all of a reporting unit, the Partnership will utilize such information. While using the discounted cash flow method, we must make estimates of projected cash flows related to assets, which include, but are not limited to, assumptions about revenue growth rates, operating margins, weighted average costs of capital and future market conditions, the use or disposition of assets, estimated remaining life of assets, and future expenditures necessary to maintain current operations. We also must make certain estimates and assumptions, including, among other things, changes in general economic conditions in regions in which our markets are located, the availability and prices of energy commodities (such as natural gas, crude oil and refined products), our ability to negotiate favorable sales agreements, the risks that natural gas exploration and production activities will not occur or be successful, our dependence on certain significant customers and producers of natural gas, and competition from other companies. Under the discounted cash flow method, the Partnership determines fair value based on estimated future cash flows and earnings before income tax, depreciation and amortization (“EBITDA”) of each reporting unit including estimates for capital expenditures, discounted to present value using the risk-adjusted industry rate, which reflects the overall level of inherent risk of the reporting unit. Cash flow projections are derived from one-year budgeted amounts and five-year operating forecasts plus an estimate of later period cash flows, all of which are evaluated by management. Subsequent period cash flows are developed for each reporting unit using growth rates that management believes are reasonably likely to occur. The annual budget process is typically completed near the annual goodwill impairment testing date, and management uses the most recent information for the annual impairment tests. The forecast is also subjected to a comprehensive update annually in conjunction with the annual budget process and is revised periodically to reflect new information and revised expectations. The estimates of future cash flows and EBITDA are subjective in nature and are subject to impacts from the business risks described in “Item 1A. Risk Factors” of the 2017 Form 10-K. While we believe we have made reasonable estimates and assumptions based on available information to calculate the fair value, if future results are not consistent with our estimates, changes in fair value estimates could result in additional impairments in future periods that could be material to our results of operations. As of December 31, 2017, the Partnership had approximately $128.9 million of goodwill on its consolidated balance sheet within seven reporting units. Of this amount, approximately $46.8 million of goodwill in two reporting units was at risk of failing the one-step quantitative test. Specifically, the Silver Dollar reporting unit in the Liquids Pipelines and Services segment had $35.7 million in goodwill. As described in Note 10 in our 2017 Form 10-K, we recorded an impairment on the Silver Dollar Reporting unit during the fourth quarter of 2017; hence, fair value approximates the adjusted net book value subsequent to impairment. The 2017 impairment related primarily to cash flow assumptions included in our discounted cash flow analysis that were adversely impacted by delays in drilling and completions experienced by producers. The Cushing reporting unit in the Terminalling Services segment had $11.1 million in goodwill as of December 31, 2017, and fair value exceeded book value by 7% . In our discounted cash flow analysis for 2017, we assumed lower utilization rates and cash flows due to required tank inspections through early 2019. The lower utilization was not previously expected in our assumptions. If the expected completion date of the inspections or future contracting rates should differ from the assumptions made in our 2017 analysis, the amount by which fair value exceeds book value could be negatively impacted. As of June 30, 2018, the Partnership had approximately $51.7 million of goodwill on its consolidated balance sheet within five reporting units as two of the seven reporting units, as of December 31, 2017, are now classified as held for sale. There were no triggering events during the six months ended June 30, 2018 and, therefore, we have not quantitatively updated our assessments.

Revenue Recognition

Revenue Recognition	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenue Recognition	(3) Revenue Recognition Effect of ASC Topic 606 Adoption - The effect of adopting Topic 606 due to the change in method to measure project progress, as discussed in Note 2 - Recent Accounting Pronouncements, is as follows (in thousands): Three months ended June 30, 2018 Six months ended June 30, 2018 Condensed Consolidated Statements of Operations As Reported Adjustments Amounts without Adoption of Topic 606 As Reported Adjustments Amounts without Adoption of Topic 606 Revenue Commodity sales $ 164,737 $ 12,535 $ 177,272 $ 323,599 $ 17,777 $ 341,376 Services 55,835 (12,304 ) 43,531 102,741 (14,985 ) 87,756 Operating expenses Costs of sales 161,508 5,409 166,917 311,674 8,574 320,248 Direct operating expenses 21,742 (4,550 ) 17,192 45,189 (5,006 ) 40,183 Operating loss (7,641 ) (628 ) (8,269 ) (20,022 ) (776 ) (20,798 ) Net loss attributable to the Partnership (17,287 ) (628 ) (17,915 ) (31,173 ) (776 ) (31,949 ) General Partner’s interest in net loss (225 ) (8 ) (233 ) (405 ) (10 ) (415 ) Limited Partners’ interest in net loss (17,062 ) (620 ) (17,682 ) (30,768 ) (766 ) (31,534 ) As of June 30, 2018 Condensed Consolidated Balance Sheets As Reported Adjustments Amounts without Adoption of Topic 606 Assets Accounts receivable, net $ 88,352 $ (76,684 ) $ 11,668 Unbilled revenue — 76,684 76,684 Other current assets 30,570 (252 ) 30,318 Other assets, net 27,984 (6,984 ) 21,000 Liabilities Other long-term liabilities 15,426 (13,865 ) 1,561 Liabilities held for sale 2,237 (690 ) 1,547 The majority of the adjustments in the table above were associated with our natural gas gathering and processing, transportation pipeline and our terminalling revenues. The magnitude of the future effect of implementing Topic 606 is dependent on future customer volumes subject to the impacted contracts and commodity prices for those volumes. Disaggregated Revenue The following table presents our segment revenues from contracts with customers disaggregated by type of activity (in thousands): Three months ended June 30, 2018 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Commodity sales: Natural gas $ 3,521 $ — $ 5,473 $ 2,587 $ — $ 11,581 NGLs 18,059 — — 33 — 18,092 Condensate 14,154 — — 63 — 14,217 Crude oil — 116,516 — — — 116,516 Other sales (1) 635 — 2 24 3,670 4,331 Services: Gathering and processing 12,463 — — 1,408 — 13,871 Transportation 143 3,626 9,857 10,229 — 23,855 Terminalling and storage — — — — 12,150 12,150 Other services (2) 534 475 235 4,175 540 5,959 Revenues from contracts with customers $ 49,509 $ 120,617 $ 15,567 $ 18,519 $ 16,360 $ 220,572 Six months ended June 30, 2018 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Commodity sales: Natural gas $ 5,427 $ — $ 12,110 $ 5,024 $ — $ 22,561 NGLs 39,209 — — 71 — 39,280 Condensate 19,802 — — 97 — 19,899 Crude oil — 232,297 — — — 232,297 Other sales (1) 818 — 6 64 8,674 9,562 Services: Gathering and processing 18,713 — — 2,274 — 20,987 Transportation 248 7,214 19,269 18,890 — 45,621 Terminalling and storage — — — — 23,983 23,983 Other services (2) 968 877 244 8,960 1,101 12,150 Revenues from contracts with customers $ 85,185 $ 240,388 $ 31,629 $ 35,380 $ 33,758 $ 426,340 _________________________ (1) Other commodity sales for our Terminalling Services segment include sales of Refined Products and Marine Products terminals. See Note 4 - Acquisitions and Dispositions. (2) Other services in our Offshore Pipelines and Services segment include asset management services. Other Items in Revenue The following table presents the reconciliation of our revenues from contracts with customers to segment revenues and total revenues as disclosed in our Condensed Consolidated Statements of Operations (in thousands): Three months ended June 30, 2018 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenues from contracts with customers $ 49,509 $ 120,617 $ 15,567 $ 18,519 $ 16,360 $ 220,572 Loss on commodity derivatives, net (294 ) (61 ) — — — (355 ) Total revenues of reportable segments $ 49,215 $ 120,556 $ 15,567 $ 18,519 $ 16,360 $ 220,217 Six months ended June 30, 2018 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenues from contracts with customers $ 85,185 $ 240,388 $ 31,629 $ 35,380 $ 33,758 $ 426,340 Loss on commodity derivatives, net (292 ) (4 ) — — — (296 ) Total revenues of reportable segments $ 84,893 $ 240,384 $ 31,629 $ 35,380 $ 33,758 $ 426,044 We may utilize derivatives instruments in connection with contracts with customers. We purchase and take title to a portion of the NGLs and crude oil that we sell, which may expose us to changes in the price of these products in our sales markets. We do not take title to the natural gas we transport and therefore have no direct commodity price exposure to natural gas. Derivative gains or losses are not included as a component of revenue from contracts with customers, but it is included in other items in revenue. Contract Balances Our contract assets and liabilities primarily relate to contracts where allocations of the transaction prices result in differences to the pattern and timing of revenue recognition as compared to contractual billings. Where payments are received in advance of recognition as revenue, contract liabilities are created. Where we have earned revenue and our right to invoice the customer is conditioned on something other than the passage of time, contract assets are created. The following table presents the change in the contract assets and liability balances during the six months ended June 30, 2018 (in thousands): Contract Assets Contract Liabilities Balance at December 31, 2017 $ — $ 2,136 Topic 606 implementation 2,555 13,246 Amounts recognized as revenue — (1,463 ) Additions 4,681 2,661 Contract balances included in assets/liabilities held for sale — (690 ) Balance at June 30, 2018 $ 7,236 $ 15,890 Current $ 252 $ 1,194 Noncurrent 6,984 14,696 Balance at June 30, 2018 $ 7,236 $ 15,890 As of June 30, 2018, in our Condensed Consolidated Balance Sheets, the current portion of contract assets is included as a component of Accounts Receivable, net of allowance for doubtful accounts, the noncurrent portion is included in Other assets, net; the current portion of contract liabilities is included in Accrued expenses and other current liabilities and the noncurrent portion is included in Other long-term liabilities. Remaining Performance Obligations The Partnership applies the practical expedients in Topic 606 and does not disclose consideration for remaining performance obligations with an original expected duration of one year or less or for variable consideration related to unsatisfied (or partially unsatisfied) performance obligations. The following table as of June 30, 2018, represents only revenue expected to be recognized from contracts where the price and quantity of the product or service are fixed: Remainder of 2018 2019 2020 2021 2022 Thereafter Total Gathering and processing based on minimum volume commitments $ 6,165 $ 12,738 $ 12,738 $ 12,715 $ 12,461 $ 19,116 $ 75,933 Transportation agreements 11,232 20,163 19,225 19,029 18,943 193,731 282,323 Terminalling and storage throughput agreements 7,070 12,896 6,204 2,694 1,582 — 30,446 Other 846 1,648 1,560 — — — 4,054 Total (1) $ 25,313 $ 47,445 $ 39,727 $ 34,438 $ 32,986 $ 212,847 $ 392,756 _________________________ (1) Includes consideration for remaining performance obligations associated with assets held-for-sale . Due to the application of the practical expedients, the table above represents only a portion of the Partnership’s expected future consolidated revenues and it is not necessarily indicative of the expected trend in total revenues for the Partnership. Certain contracts do not meet the requirements for presentation in the table above due to the term being one year or less and due to variability in the amount of performance obligation remaining, variability in the timing of recognition or variability in consideration. Acreage dedications do require us to perform future services but do not contain a minimum level of services and are therefore excluded from this presentation. Long-term supply and logistics arrangements contain variable timing, volumes and/or consideration and are excluded from this presentation.

Acquisitions and Dispositions

Acquisitions and Dispositions	6 Months Ended
	Jun. 30, 2018
Discontinued Operations and Disposal Groups [Abstract]
Acquisition and Dispositions	(4) Acquisitions and Dispositions Acquisitions The 2017 acquisitions are as follows: • 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 exchange. As both we and JPE were controlled by ArcLight affiliates, the acquisition represented a transaction among entities under common control. The accompanying condensed consolidated financial statements and related notes present the combined financial position, results of operations, cash flows and equity of JPE at historical cost. • On June 2, 2017, we acquired 100% of Viosca Knoll Gathering System (“VKGS”) from Genesis Energy, L.P. for total consideration of approximately $32.0 million in cash. This was accounted for as a business combination. • On August 8, 2017, we acquired 100% of the interest in Panther Offshore Gathering Systems, LLC (“POGS”), Panther Pipeline, LLC (“PPL”) and Panther Operating Company, LLC (“POC” and, together with POGS and PPL, “Panther”) from Panther Asset Management LLC for approximately $60.9 million in cash, issuance of common units and other considerations. This was accounted for as a business combination. • On November 3, 2017, we completed the acquisition of 100% of the equity interests in Trans-Union Interstate Pipeline, LP (“Trans-Union”) from affiliates of ArcLight, for a total consideration of approximately $49.4 million . The consideration consisted of approximately $16.9 million cash funded from borrowings under our revolving credit facility and the assumption of $32.5 million of non-recourse debt. This was accounted for as an acquisition between entities under common control. Additionally, we acquired the following interests in 2017 that are accounted for as investments in unconsolidated affiliates: • On August 8, 2017, we entered into a new joint venture agreement with Targa Midstream Services, LLC (“Targa”) by which our previously wholly owned subsidiary Cayenne Pipeline, LLC became the Cayenne joint venture between Targa and us. • On September 29, 2017, we acquired an additional 15.5% equity interest in Class A units of the Delta House platform (“Delta House”) from affiliates of ArcLight for total cash consideration of approximately $125.4 million . • On October 27, 2017, American Midstream Emerald, LLC, a wholly-owned subsidiary of the Partnership, entered into a purchase and sale agreement with Emerald Midstream, LLC, an ArcLight affiliate, to purchase an additional 17.0% equity interest in Destin for total cash consideration of $30.0 million . For further discussion, see the Note 3 - Acquisitions in our 2017 Form 10-K. The proforma effects of 2017 acquisitions were not material to our Condensed Consolidated Statements of Operations and therefore have not been presented separately. Planned Dispositions Assets Held for Sale In the second quarter of 2017, we began executing a capital optimization strategy to simplify our business and redeploy capital from non-core assets toward higher return and growth opportunities. In addition to the sale of our propane business (“Propane Business”) discussed below under Discontinued Operations , we determined that the terminalling assets were not integral to our core strategies; therefore, we began contemplating their disposition. We actively began marketing our Terminalling Services segment assets to use the proceeds to fund future acquisitions and growth projects. In the first half of 2018, we entered into definitive agreements for the sale of the following businesses: • On February 16, 2018, we entered into a definitive agreement for the sale of our refined products terminals (the “Refined Products”) to DKGP Energy Terminals LLC (“DKGP”), for approximately $138.5 million in cash, subject to working capital adjustments. During June 2018, we were notified that the Federal Trade Commission was requesting additional information and documentary materials with respect to the planned sale. We are continuing to market the Refined Products terminals. We continue to present the assets and liabilities of the Refined Products as held for sale. See Note 22 - Subsequent Events for additional information regarding the sale of Refined Products. • On June 16, 2018, we entered into a definitive agreement for the sale of our marine liquids terminals (the “Marine Products”) to institutional investors for approximately $210.0 million in cash, subject to working capital adjustments. The divestiture of the Marine Products, including the Harvey and Westwego terminals located in the Port of New Orleans and the Brunswick terminal located in the Port of Brunswick in Georgia, is a continuation of the Partnership's previously announced non-core asset divestiture program. Accordingly, we have presented the Marine Products assets and liabilities as held for sale as of June 30, 2018. See Note 22 - Subsequent Events for additional information regarding the sale of Marine Products. The planned dispositions of the Refined Products and Marine Products terminals do not meet the criteria for discontinued operations, as we believe the sale of Refined Products and Marine Products will not significantly impact our results of operations or financial condition. As of June 30, 2018, certain remaining assets in the Terminalling Services segment do not meet the criteria to be classified as held for sale. Included in the disposal groups are the following assets and liabilities at June 30, 2018 (in thousands): Refined Products Marine Products Business (1) Business (2) Total Cash and cash equivalents $ — $ 364 $ 364 Accounts receivable, net 1,834 2,521 4,355 Inventory 506 31 537 Other current assets 213 144 357 Property, plant and equipment, net 32,332 84,661 116,993 Goodwill 61,163 16,262 77,425 Intangible assets 29,403 — 29,403 Other non-current assets 692 3 695 Total assets held for sale $ 126,143 $ 103,986 $ 230,129 Accounts payable $ 44 $ 152 $ 196 Accrued gas purchases 72 — 72 Accrued expenses and other current liabilities 991 406 1,397 Other long-term liabilities 572 — 572 Total liabilities held for sale $ 1,679 $ 558 $ 2,237 _________________________ (1) Net income from continuing operations before income taxes for the Refined Products Business were as follows: • $4.3 million and $1.6 million for the three months ended June 30, 2018 and 2017, respectively; and • $6.7 million and $3.4 million for the six months ended June 30, 2018 and 2017, respectively. (2) Net income from continuing operations before income taxes for the Marine Products Business were as follows: • $3.5 million and $2.5 million for the three months ended June 30, 2018 and 2017, respectively; and • $5.1 million and $5.2 million for the six months ended June 30, 2018 and 2017, respectively. Discontinued Operations On September 1, 2017, we completed the disposition of our Propane Business pursuant to the Membership Interest Purchase Agreement dated July 21, 2017, between AMID Merger LP, a wholly owned subsidiary of the Partnership, and SHV Energy N.V. Through the transaction, we divested Pinnacle Propane’s 40 service locations; Pinnacle Propane Express’ cylinder exchange business and related logistics assets; and the Alliant Gas utility system. Prior to the sale, we moved the trucking business from the Propane Marketing Services segment to the Liquid Pipelines and Services segment. With the disposition of the Propane Business, we eliminated the Propane Marketing Services segment. In connection with the transaction, we received approximately $170.0 million in cash, net of customary closing adjustments. We recorded a gain of $47.4 million , net of $2.5 million of transaction costs, which was included in (Gains) losses on sale of assets and business in our Condensed Consolidated Statement of Operations in the period ended September 30, 2017. We have reported the accounts and the results of our Propane Business as discontinued operations in our Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2017 . Summarized financial information related to the Propane Business is set forth in the tables below (in thousands): Three months ended June 30, Six months ended June 30, 2017 2017 Total revenue $ 31,603 $ 67,157 Total operating expenses 33,402 69,707 Operating loss (1,799 ) (2,550 ) Other income 42 83 Income tax expense (44 ) (44 ) Loss from discontinued operations $ (1,801 ) $ (2,511 ) Depreciation and amortization $ 3,687 $ 7,468 Capital expenditures $ 1,302 $ 2,421 Operating non-cash items Unrealized loss on derivative contracts, net $ (60 ) $ (961 )

Inventory (Notes)

Inventory (Notes)	6 Months Ended
	Jun. 30, 2018
Inventory Disclosure [Abstract]
Inventory	(5) Inventory Inventory consists of the following (in thousands): June 30, 2018 December 31, 2017 Crude oil $ 2,184 $ 1,553 NGLs 357 347 Refined products — 934 Materials, supplies and equipment 120 132 Total inventory $ 2,661 $ 2,966

Other Current Assets

Other Current Assets	6 Months Ended
	Jun. 30, 2018
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Other Current Assets	(6) Other Current Assets Other current assets consist of the following (in thousands): June 30, 2018 December 31, 2017 Prepaid expenses $ 7,196 $ 8,944 Insurance receivables 881 1,741 Due from related parties 6,773 4,362 Other receivables 8,801 5,187 Risk management assets 6,919 3,186 Total other current assets $ 30,570 $ 23,420

Risk Management Activities

Risk Management Activities	6 Months Ended
	Jun. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Risk Management Activities	(7) Risk Management Activities We are exposed to certain market risks related to the volatility of commodity prices and changes in interest rates. To monitor and manage these market risks, we have established comprehensive risk management policies and procedures. We do not enter into derivative instruments for any purpose other than hedging commodity price risk, interest rate risk, and weather risk. We do not speculate using derivative instruments. Commodity Derivatives To manage the impact of the risks associated with changes in the market price of NGL, crude oil and refined products in our day-to-day business, 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 commodity is delivered . In accordance with ASC 815, Derivatives and Hedging, if it is determined that a transaction designated as NPNS no longer meets the scope of the exception, the fair value of the related contract is recorded on the balance sheet (as an asset or liability) and the difference between the fair value and the contract amount is immediately recognized through earnings. We measure our commodity derivatives at fair value using the income approach, which discounts the future net cash settlements expected under the derivative contracts to a present value. These valuations utilize indirectly observable (“Level 2”) inputs, including commodity prices observable at commonly quoted intervals. The following table summarizes the net notional volumes of our outstanding commodity-related derivatives, excluding those contracts that qualified for the NPNS exception as of June 30, 2018 and December 31, 2017 , none of which were designated as hedges for accounting purposes. June 30, 2018 December 31, 2017 Commodity Swaps Volume Maturity Volume Maturity NGLs Fixed Price (gallons) 2,188,200 January 2019 — — Interest Rate Swaps To manage the impact of the interest rate risk associated with our Credit Agreement, as defined in Note 13 - Debt Obligations , we enter into interest rate swaps from time to time, effectively converting a portion of the cash flows related to our long-term variable rate debt into fixed rate cash flows. As of June 30, 2018 , and December 31, 2017 , we had a combined notional principal amount of $550.0 million respectively of variable-to-fixed interest rate swap agreements. As of June 30, 2018 , the maximum length of time over which we have hedged a portion of our exposure due to interest rate risk is through December 31, 2022. The fair value of our interest rate swaps was estimated using a valuation methodology based upon forward interest rates and volatility curves as well as other relevant economic measures, if necessary. Discount factors may be utilized to extrapolate a forecast of future cash flows associated with long dated transactions or illiquid market points. The inputs, which represent Level 2 inputs in the valuation hierarchy, are obtained from independent pricing service providers, and we have made no adjustments to those prices. Weather Derivative In the second quarters of 2018 and 2017, we entered into a yearly weather derivative arrangement to mitigate the impact of potential unfavorable weather on our operations under which we could receive payments totaling up to $20.0 million and $30.0 million , respectively, in the event that a hurricane of certain strength passes through the areas identified in the derivative agreement. The weather derivative, which is accounted for using the intrinsic value method, was entered into with a single counterparty, and we were not required to post collateral. We paid $1.0 million and $1.1 million in premiums during the three and six months ended June 30, 2018 and 2017 , respectively. Premiums are amortized to Direct operating expenses on a straight-line basis over the one -year term of the contract. Unamortized amounts associated with the weather derivatives were approximately $0.9 million and $0.5 million as of June 30, 2018 and December 31, 2017 , respectively, and are included in Other current assets on the Condensed Consolidated Balance Sheets. Financial Instruments Measured at Fair Value on a Recurring Basis - The following table summarizes the fair values of our derivative contracts (before netting adjustments) included in the Condensed Consolidated Balance Sheets (in thousands): Asset Derivatives Liability Derivatives Type Balance Sheet Classification June 30, December 31, 2017 June 30, December 31, 2017 Commodity derivatives Accrued expenses and other current liabilities $ — $ — $ (240 ) $ — Interest rate swaps Other current assets 5,970 2,677 — — Interest rate swaps Other assets net 11,605 8,807 — — Weather derivatives Other current assets 949 509 — — Total $ 18,524 $ 11,993 $ (240 ) $ — As of June 30, 2018 , and December 31, 2017, there were no offsets to the fair value of our derivative assets and liabilities on a gross basis in the Condensed Consolidated Balance Sheets, subject to enforceable master netting arrangements. For each of the three and six months ended June 30, 2018 and 2017 , the realized and unrealized gains (losses) associated with our commodity, interest rate and weather derivative instruments were recorded in our Condensed Consolidated Statements of Operations as follows (in thousands): Three months ended June 30, Six months ended June 30, Statement of Operations Classification Realized Unrealized Realized Unrealized 2018 Loss on commodity derivatives, net $ (174 ) $ (181 ) $ (56 ) $ (240 ) Interest expense 1,285 920 2,635 6,091 Direct operating expenses (272 ) — (550 ) — Total gain on derivatives recognized in net loss $ 839 $ 739 $ 2,029 $ 5,851 2017 Gains (losses) on commodity derivatives, net $ 192 $ 7 $ 613 $ (49 ) Interest expense — (1,693 ) (70 ) (2,010 ) Direct operating expenses (218 ) — (475 ) — Total (loss) gain on derivatives recognized in net loss $ (26 ) $ (1,686 ) $ 68 $ (2,059 ) Fair Value Financial Instruments Not Measured at Fair Value on a Recurring Basis - The following table presents the carrying value and estimated fair value of our financial instruments that are not measured at fair value on a recurring basis as of June 30, 2018 and December 31, 2017. Short-term and long-term debt are recorded at amortized cost in the Condensed Consolidated Balance Sheets. June 30, 2018 December 31, 2017 Carrying Amount Fair Value Carrying Amount Fair Value Non-Derivatives Liabilities 8.5% Senior Unsecured Notes $ 418,537 $ 420,137 $ 418,421 $ 437,062 3.77% Senior Secured Notes 55,447 50,822 56,005 53,845 3.97% Trans-Union Secured Senior Notes 30,824 28,053 31,692 30,221 Total $ 504,808 $ 499,012 $ 506,118 $ 521,128 The fair value of debt instruments are valued using a market approach based on quoted prices for similar instruments traded in active markets are classified as Level 2 within the fair value hierarchy. All financial instruments in the table above are classified as Level 2. The carrying value of amounts outstanding under the Credit Agreement approximates the related fair value, as interest charges vary with market rate conditions. The carrying value of all non-derivative financial instruments included in current assets (including cash, cash equivalents and restricted cash and accounts receivable) and current liabilities (including accounts payable but excluding short-term debt) approximates the applicable fair value due to the short maturity of those instruments.

Property, Plant and Equipment

Property, Plant and Equipment	6 Months Ended
	Jun. 30, 2018
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	(8) Property, Plant and Equipment Property, plant and equipment, net, consists of the following (in thousands): Useful Life (in years) June 30, December 31, Land Infinite $ 14,635 $ 18,145 Construction in progress N/A 52,811 55,622 Buildings and improvements 4 to 40 10,116 16,235 Transportation equipment 5 to 15 22,527 22,697 Processing and treating plants 8 to 40 123,210 123,138 Pipelines, compressors and right-of-way 3 to 40 1,004,992 974,301 Storage 3 to 40 46,398 146,105 Equipment 3 to 31 61,353 80,220 Total property, plant and equipment 1,336,042 1,436,463 Accumulated depreciation (343,383 ) (340,878 ) Property, plant and equipment, net $ 992,659 $ 1,095,585 At June 30, 2018 and December 31, 2017 , gross property, plant and equipment included $374.2 million and $367.6 million , respectively, related to our FERC regulated interstate and intrastate assets. Depreciation and amortization expense totaled $18.2 million and $18.3 million for the three months ended June 30, 2018 and 2017 , respectively, and $36.8 million and $36.8 million for both the six months ended June 30, 2018 and 2017 . Capitalized interest was $0.9 million and $0.5 million for the three months ended June 30, 2018 and 2017 , respectively, and $1.5 million and $1.5 million for the six months ended June 30, 2018 and 2017 , respectively.

Goodwill and Intangible Assets

Goodwill and Intangible Assets	6 Months Ended
	Jun. 30, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	(9) Goodwill and Intangible Assets Goodwill consists of the following (in thousands): June 30, 2018 December 31, 2017 Liquid Pipelines and Services $ 35,708 $ 35,708 Terminalling Services 11,043 88,466 Offshore Pipelines and Services 4,972 4,692 Total $ 51,723 $ 128,866 The change in the Terminalling Services segment goodwill relates to the Refined Products and the Marine Products which were classified as held for sale at June 30, 2018 . See Note 4 - Acquisitions and Dispositions for further discussion. 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): June 30, 2018 Gross carrying amount Accumulated amortization Net carrying amount Customer relationships $ 64,745 $ (15,548 ) $ 49,197 Customer contracts 94,692 (50,664 ) 44,028 Dedicated acreage 42,547 (6,904 ) 35,643 Collaborative arrangements 11,884 (1,839 ) 10,045 Noncompete agreements 1,064 (1,064 ) — Other 198 (28 ) 170 Total $ 215,130 $ (76,047 ) $ 139,083 December 31, 2017 Gross carrying amount Accumulated amortization Net carrying amount Customer relationships $ 110,483 $ (29,965 ) $ 80,518 Customer contracts 94,692 (48,173 ) 46,519 Dedicated acreage 42,547 (6,216 ) 36,331 Collaborative arrangements 11,884 (1,415 ) 10,469 Noncompete agreements 1,064 (1,064 ) — Other 198 (25 ) 173 Total $ 260,868 $ (86,858 ) $ 174,010 Amortization expense related to our intangible assets totaled $2.5 million and $7.6 million for the three months ended June 30, 2018 and 2017 , respectively, and $5.2 million and $14.2 million for the six months ended June 30, 2018 and 2017 , respectively. The estimated aggregate annual amortization expected to be recognized for the remainder of 2018 and each of the four succeeding fiscal years is $5.1 million , $10.2 million , $10.2 million , $10.2 million and $9.3 million , respectively.

Investment in Unconsolidated Af

Investment in Unconsolidated Affiliates	6 Months Ended
	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Investment in Unconsolidated Affiliates	(10) Investments in Unconsolidated Affiliates The following table presents the activity in our equity method investments in unconsolidated affiliates (in thousands): Delta House (1) Emerald Transactions FPS (2,4) OGL (2,4) Destin (4) Tri-States (3) Okeanos (4) Wilprise (3) Cayenne JV (3) Total Ownership % - 12/31/2017 35.7% 35.7% 66.7% 16.7% 66.7% 25.3% 50.0% Ownership % - 6/30/2018 35.7% 35.7% 66.7% 16.7% 66.7% 25.3% 50.0% Balances at December 31, 2017 $ 90,412 $ 46,932 $ 124,245 $ 53,057 $ 22,445 $ 4,689 $ 6,654 $ 348,434 Earnings in unconsolidated affiliates 5,267 3,916 4,449 1,880 4,781 510 2,316 23,119 Contributions 826 — — — — — 3,705 4,531 Distributions (6,246 ) (7,972 ) (17,872 ) (3,316 ) (8,010 ) (538 ) (600 ) (44,554 ) Balances at June 30, 2018 $ 90,259 $ 42,876 $ 110,822 $ 51,621 $ 19,216 $ 4,661 $ 12,075 $ 331,530 ___________________________________________________ (1) Represents direct and indirect ownership interests in Class A units and common units. (2) FPS denotes Floating Production System LLC whereas OGL denotes Oil & Gas Lateral LLC. (3) Included in our Liquid Pipelines and Services segment. (4) Included in our Offshore Pipelines and Services segment. The following tables present the summarized combined financial information for our equity investments (amounts represent 100% of investee financial information) (in thousands): Balance Sheets: June 30, 2018 December 31, 2017 Current assets $ 65,283 $ 80,405 Non-current assets 1,272,593 1,288,862 Current liabilities 117,591 130,904 Non-current liabilities 447,654 436,584 Three months ended June 30, Six months ended June 30, Statements of Operations: 2018 2017 (1) 2018 2017 (1) Revenue $ 51,790 $ 105,373 $ 108,689 $ 203,366 Operating expenses 8,213 25,781 14,507 51,977 Net income 27,303 76,414 60,149 145,532 _________________________ (1) In August 2017, we acquired 100% of the interest in POGS, the outstanding interests in one of our equity investments. We have consolidated this entity from the acquisition date. See Note 4 - Acquisitions and Dispositions for further discussion.

Accrued Expenses and Other Curr

Accrued Expenses and Other Current Liabilities	6 Months Ended
	Jun. 30, 2018
Other Liabilities Disclosure [Abstract]
Accrued Expenses and Other Current Liabilities	(11) Accrued Expenses and Other Current Liabilities Accrued expenses and other current liabilities consists of the following (in thousands): June 30, 2018 December 31, 2017 Capital expenditures $ 8,137 $ 10,721 Accrued interest 6,485 3,190 Convertible preferred unit distributions 8,474 — Current portion of asset retirement obligation 6,416 6,416 Additional Blackwater acquisition consideration 5,000 5,000 Taxes payable 3,676 5,263 Due to related parties 5,225 6,609 Royalties, gas imbalance and leases payables 6,423 7,905 Professional fees 4,566 1,848 Other 12,993 21,902 Total accrued expenses and other current liabilities $ 67,395 $ 68,854

Asset Retirement Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	(12) Asset Retirement Obligations We record a liability for the fair value of asset retirement obligations and conditional asset retirement obligations (collectively referred to as “AROs”) that we can reasonably estimate, on a discounted basis, in the period in which the liability is incurred. Generally, the fair value of the liability is calculated using discounted cash flow techniques and based on internal estimates and assumptions related to (i) future retirement costs, (ii) future inflation rates, and (iii) credit adjusted risk-free interest rates. Significant increases or decreases in the assumptions would result in a significant change to the fair value measurement. Certain assets related to our Offshore Pipelines and Services segment have regulatory obligations to perform remediation, and in some instances dismantlement and removal activities, when the assets are abandoned. These AROs include varying levels of activity including disconnecting inactive assets from active assets, cleaning and purging assets, and in some cases, completely removing the assets and returning the land to its original state. These assets have been in existence for many years and with regular maintenance will continue to be in service for many years to come. It is not possible to predict when demand for these transmission services will cease, however, we do not believe that such demand will cease for the foreseeable future. The majority of the current portion of our AROs, which is included in Accrued Expenses and Other Current Liabilities in our Condensed Consolidated Balance Sheet, is related to the retirement of the Midla pipeline. For further discussion related to the retirement of the Midla Pipeline, see the Note 14 - Debt Obligations in the 2017 Form 10-K. The following table presents activity in our asset retirement obligations for the six months ended June 30, 2018 (in thousands): Non-current balance $ 66,194 Current balance 6,416 Balances at December 31, 2017 72,610 Additions 260 Expenditures (7 ) Accretion expense 911 Balances at June 30, 2018 73,774 Less: current portion 6,416 Noncurrent asset retirement obligation $ 67,358 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. Those deposits, in our Condensed Consolidated Balance Sheets as of June 30, 2018 and December 31, 2017, are included in Restricted cash-long term.

Debt Obligations

Debt Obligations	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Debt Obligations	(13) Debt Obligations Our outstanding debt consists of the following (in thousands): June 30, 2018 December 31, 2017 Revolving credit facility $ 776,300 $ 697,900 8.50% Senior unsecured notes, due 2021 425,000 425,000 3.77% Senior secured notes, due 2031 (non-recourse) 57,679 58,324 3.97% Senior secured notes, due 2032 (non-recourse) 31,148 32,025 Other debt 579 4,989 Total debt obligations 1,290,706 1,218,238 Unamortized debt issuance costs (9,020 ) (9,231 ) Total debt 1,281,686 1,209,007 Less: Current portion, including unamortized debt issuance costs (3,624 ) (7,551 ) Long term debt $ 1,278,062 $ 1,201,456 AMID Revolving Credit Agreement On June 29, 2018, we amended our $900 million revolving credit facility agreement, dated March 8, 2017 (the “Original Credit Agreement”), by entering into that certain First Amendment to Second Amended and Restated Credit Agreement (the “Amendment” and, the Original Credit Agreement as amended by the Amendment, the “Credit Agreement”; capitalized terms used but not defined herein shall have the meanings assigned thereto in the Credit Agreement) with a syndicate of lenders and Bank of America, N.A., as administrative agent. The Amendment adds a required prepayment event in an amount equal to 100% of the net cash proceeds received from the Marine Products and Refined Products asset sales and any other disposition greater than $5 million . Among other things, the Amendment also amends our borrowing capacity as follows: • upon consummation of the Marine Products sale, the aggregate commitments under the Credit Agreement shall be automatically reduced by $200.0 million ; • upon consummation of the Refined Products sale, the aggregate commitments under the Credit Agreement shall be automatically reduced by 50% of the net cash proceeds of such disposition; and • upon consummation of any disposition greater than $15 million , the aggregate commitments under the Credit Agreement shall be automatically reduced by 25% of the net cash proceeds of such disposition. The Amendment adds a new pricing tier of LIBOR + 3.50% when Consolidated Total Leverage Ratio equals or exceeds 5.0 : 1.0 . The Credit Agreement includes the following financial covenants, as amended by the Amendment and defined in the Credit Agreement, which financial covenants will be tested on a quarterly basis, for the fiscal quarter then ending: Consolidated Interest Coverage Ratio Consolidated Total Leverage Ratio Consolidated Secured Leverage Ratio June 30, 2018 2.50:1.00 6.15:1.00 4.00:1.00 September 30, 2018 2.00:1.00 6.25:1.00 3.75:1.00 December 31, 2018 1.75:1.00 5.50:1.00 3.50:1.00 March 31, 2019 1.75:1.00 5.00:1.00 (1) 3.50:1.00 June 30, 2019 and thereafter 2.00:1.00 5.00:1.00 (1) 3.50:1.00 ___________________________ (1) 5.50 :1.00 during a Specified Acquisition Period The revolving credit facility is scheduled to mature on September 5, 2019. As of June 30, 2018 , after giving effect to the amendments to the ratios, we were in compliance with our Credit Agreement financial covenants, including those shown below: Ratio Actual Minimum Consolidated Interest Coverage Ratio 3.11 Maximum Allowable Consolidated Total Leverage Ratio 5.42 Maximum Allowable Consolidated Secured Leverage Ratio 3.50 As of June 30, 2018 , we had approximately $776.3 million of borrowings, $39.0 million of letters of credit outstanding under the Credit Agreement and approximately $71.6 million of available borrowing capacity which can be increased up to $84.7 million , conditional upon compliance with existing covenants. For the first half of 2018 and 2017, the weighted average interest rate on borrowings under this facility was approximately 5.81% and 4.67% , respectively. Senior Unsecured Notes Our senior unsecured notes include an optional redemption whereby we may elect to redeem the notes, in whole or in part from time-to-time, for a premium. On and after December 15, 2018, we may redeem all or a part of the 8.50% Senior Notes, at the redemption prices set forth below, plus accrued and unpaid interest, if redeemed during the twelve -month period beginning on December 15 of the years indicated below: Year Percentage 2018 104.250% 2019 102.125% 2020 and thereafter 100.000% See Note 14 - Debt Obligations in our 2017 Form 10-K for additional information relating to our outstanding debt.

Convertible Preferred Units (No

Convertible Preferred Units (Notes)	6 Months Ended
	Jun. 30, 2018
Partners' Capital [Abstract]
Convertible Preferred Units	(14) Convertible Preferred Units Our convertible preferred units consist of the following (in thousands): Series A Series C Total Units $ Units $ $ December 31, 2017 10,719 $ 191,798 8,965 $ 125,382 $ 317,180 Paid in kind unit distributions 291 — 277 — — June 30, 2018 11,010 $ 191,798 9,242 $ 125,382 $ 317,180 Affiliates of our General Partner hold and participate in quarterly distributions on our convertible preferred units, with such distributions being made in cash, paid-in-kind units or a combination thereof at the election of the Board of Directors of our General Partner (the “Board”). 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 accrue interest until paid. Series A-1 Convertible Preferred Units On April 15, 2013, the Partnership, our General Partner and AIM Midstream Holdings LLC 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, LLC and contributed the High Point System, our 574 mile transmission system located in southeast Louisiana and the Gulf of Mexico, and $15.0 million in cash to us in exchange for 5,142,857 of our Series A-1 Units. The holders of Series A-1 Units receive distributions prior to any 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 at any time. As of June 30, 2018 , the conversion price was $15.11 , and the conversion ratio is 1: 1.1582 . 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, 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. 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 affiliates’ 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 $100.0 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 June 30, 2018 , the conversion price was $15.11 , and the conversion ratio is 1: 1.1582 . 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 the Securities Act of 1933, as amended (the “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 June 30, 2018 , the conversion price was $13.28 , and the conversion ratio is 1 : 1.0542 . 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 “Fair Value Measurements and Disclosures” (“ASC 820”). The estimated fair value of $4.41 per warrant unit was determined using a Black-Scholes model and the following significant assumptions: (i) a dividend yield of 18% , (ii) common unit volatility of 42% and (iii) the seven -year term of the warrant to arrive at an aggregate fair value of $4.5 million . As conversion is at the option of the holder and redemption is contingent upon a future event, which is outside the control of the Partnership, the Series A-1, A-2 and C Units have been classified as mezzanine equity in the Condensed Consolidated Balance Sheets.

Partners Capital

Partners Capital	6 Months Ended
	Jun. 30, 2018
Equity [Abstract]
Partners’ Capital	(15) Partners’ Capital Our capital accounts are comprised of approximately 1.3% notional General Partner interests and 98.7% limited partner interests as of June 30, 2018 . Our limited partners have limited rights of ownership as provided for under our Partnership Agreement and the right to participate in our distributions. Our General Partner manages our operations and participates in our distributions, including certain incentive distributions pursuant to the incentive distribution rights that are non-voting limited partner interests held by our General Partner. Pursuant to our Partnership Agreement, our General Partner participates in losses and distributions based on its interest. The General Partner’s participation in the allocation of losses and distributions is not limited, and therefore, such participation can result in a deficit to its capital account. As such, allocation of losses and distributions, including distributions for previous transactions between entities under common control, has resulted in a deficit to the General Partner’s capital account included in our Condensed Consolidated Balance Sheets. Outstanding Units The following table presents unit activity (in thousands): General Limited Partner Interest Balances at December 31, 2017 965 52,711 LTIP vesting — 261 Balances at June 30, 2018 965 52,972 General Partner Units In order for our General Partner to maintain its ownership percentage in us, our General Partner paid $3.9 million for the issuance of 272,811 additional notional General Partner units for the six months ended June 30, 2017. We issued 300 additional General Partner units for the three and six months ended June 30, 2018 . Distributions Preferred Units Under the Partnership’s agreement of limited partnership, the Partnership is obligated to pay cumulative distributions each quarter on the Series A preferred units (which consists of the Series A-1 and A-2) and Series C preferred units in an amount equal to the greater of $0.4125 , or the distribution declared on the common units. As such, the distributions are accrued at each quarter-end (the “reporting quarter”) based on the subsequent board approval of the distribution method (in the “subsequent quarter”), which may be settled in cash or paid-in-kind (“PIK”) units. To the extent the distribution is to be settled in cash, the distributions are accrued in the reporting quarter and the cash is paid in the subsequent quarter. To the extent the distribution is to be settled in PIK units, the distribution is recognized directly to equity in the reporting quarter. Limited Partner Units (Common Units) The following table reflects distributions declared and paid through June 30, 2018 (in thousands, except per unit data): Date Declared Distribution Payment Date General Partner Limited Partner Total Cash Distributions Cash Distributions Per Common Unit April 26, 2018 May 15, 2018 $ 287 $ 21,853 $ 22,140 $ 0.4125 January 26, 2018 February 14, 2018 $ 290 $ 21,745 $ 22,035 $ 0.4125 On July 27, 2018, we announced that the Board of Directors of our general partner declared a quarterly cash distribution of $0.1031 per common unit, which represents the distribution for the second quarter of 2018 and will be paid in the third quarter of 2018. See Note 22 - Subsequent Events for more information. The following table details cash distributions paid or accrued as of, and for, the three and six months ended June 30, 2018 (in thousands): Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 Series A Units Cash Paid $ 4,542 $ 2,117 $ 4,542 $ 4,644 Accrued (1) 4,542 4,069 4,542 4,069 Paid-in-kind units — 2,181 3,767 4,914 Series C Units Cash Paid 3,812 3,627 3,812 7,254 Accrued (1) 3,812 3,627 3,812 3,627 Paid-in-kind units — — 4,309 — Series D Units Cash Paid — 963 — 1,925 Accrued — 963 — 963 Limited Partners’ Units (2) Cash Paid 21,853 21,390 43,598 46,303 General Partners’ Units (3) Cash Paid 287 201 577 368 Summary Cash Paid $ 30,494 $ 28,298 $ 52,529 $ 60,494 Accrued (1) 8,354 8,659 8,354 8,659 Paid-in-kind units — 2,181 8,076 4,914 __________________________ (1) Can be paid in either Cash, PIK or a combination of both. (2) Limited Partner distributions do not include $5.5 million and $21.4 million of distributions declared in the third quarter which relate to the second quarter of 2018 and 2017, respectively. (3) General Partner distributions do not include $0.1 million and $0.3 million of distributions declared in the third quarter which relate to the second quarter of 2018 and 2017, respectively. Fair Value Determination of PIK of Preferred Units The fair value of the PIK distributions was determined using the market and income approaches, requiring significant inputs that are not observable in the market and thus represent a Level 3 measurement. 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 $0.31 per unit to $2.05 per unit using a Black-Scholes model, (iii) assumed discount rates ranging from 5.80% to 6.23% and (iv) assumed growth rates of 1.0% .

Net Loss per Limited Partner Un

Net Loss per Limited Partner Unit	6 Months Ended
	Jun. 30, 2018
Earnings Per Share [Abstract]
Net Loss per Limited Partner Unit	(16) Net Loss per Limited Partner Unit As discussed in Note 4 - Acquisitions and Dispositions , the JPE Merger on March 8, 2017 was a combination between entities under common control. As a result, prior periods were retrospectively adjusted to furnish comparative information. Accordingly, the prior period earnings combining both entities were allocated among our General Partners and common unitholders assuming JPE units were converted into our common units in the comparative historical periods. The calculation of basic and diluted limited partners' net loss per common unit is summarized below (in thousands, except per unit amounts): Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 Loss from continuing operations $ (17,274 ) $ (25,901 ) $ (31,116 ) $ (54,072 ) Less: Net income attributable to noncontrolling interests 13 1,462 57 2,765 Loss attributable to the Partnership (17,287 ) (27,363 ) (31,173 ) (56,837 ) Less: Distributions on Series A Units 4,542 4,069 9,084 8,367 Distributions on Series C Units 3,812 3,627 7,624 7,254 Distributions on Series D Units — 963 — 1,925 General Partner's distribution 72 277 361 476 General Partner's share in undistributed loss (403 ) (784 ) (986 ) (1,541 ) Loss attributable to Limited Partners (25,310 ) (35,515 ) (47,256 ) (73,318 ) Loss from discontinued operations, net of tax — (1,801 ) — (2,511 ) Net loss attributable to Limited Partners $ (25,310 ) $ (37,316 ) $ (47,256 ) $ (75,829 ) Weighted average number of common units outstanding - Basic and Diluted 52,969 51,870 52,869 51,870 Limited Partners' net loss per common unit - Basic and Diluted Loss from continuing operations $ (0.48 ) $ (0.69 ) $ (0.89 ) $ (1.41 ) Loss from discontinued operations — (0.03 ) — (0.05 ) Net loss (1) $ (0.48 ) $ (0.72 ) $ (0.89 ) $ (1.46 ) _____________________________________ (1) Potential common unit equivalents are antidilutive for all periods presented and, as a result, 23.9 million and 24.0 million potential common unit equivalents for the three and six months ended June 30, 2018 and 2017, respectively and have been excluded from the determination of diluted limited partners' net loss per common unit.

Incentive Compensation

Incentive Compensation	6 Months Ended
	Jun. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Incentive Compensation	(17) Incentive Compensation All equity-based awards issued under the long-term incentive plan (“LTIP”) consist of either restricted (“RSUs”) or performance-based (“PSUs”) phantom units, or option grants. Future awards may be granted at the discretion of the Compensation Committee of the Board and subject to approval by the Board. As of June 30, 2018, there were 3,665,180 common units available for future grants under the LTIP. The following table presents the components of equity-based compensation expense for the three and six months ended June 30, 2018 and 2017 (in thousands): Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 Grant Type: RSU $ 835 $ 1,177 $ 1,534 $ 5,195 PSU 330 — 630 — Options 15 19 30 38 Total $ 1,180 $ 1,196 $ 2,194 $ 5,233 During the six months ended June 30, 2018, we granted 809,357 RSU’s at a weighted-average fair value per unit of $8.56 , vested 336,211 RSU’s at a weighted-average fair value per unit of $6.26 and forfeited 253,245 RSU’s at a weighted-average fair value per unit of $5.87 . Unrecognized compensation expense related to RSU’s was $10.2 million at June 30, 2018. During the six months ended June 30, 2018, we did not grant any options or performance-based awards under our LTIP. Unrecognized compensation expense related to options and performance-based awards was $0.1 million and $5.6 million , respectively, at June 30, 2018. Defined Contribution Plan For the three and six months ended June 30, 2018 and 2017 , compensation expense associated with our 401(k)-defined contribution plan’s employer matching was $0.5 million and $0.4 million , respectively, and $1.3 million and $0.9 million , respectively. There was no change to the defined contribution plan.

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	(18) Commitments and Contingencies Legal Proceedings We are not currently party to any pending litigation or governmental proceedings, other than ordinary routine litigation incidental to our business. While the ultimate impact of any proceedings cannot be predicted with certainty, our management believes that the resolution of any of our pending proceedings will not have a material adverse effect on our financial condition or results of operations. Environmental Matters We are subject to federal and state laws and regulations relating to the protection of the environment. Environmental risk is inherent in 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.

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2018
Related Party Transactions [Abstract]
Related Party Transactions	(19) Related Party Transactions To the extent applicable, our discussion below includes the nature of our relationship and activities that we had with our Related Parties, as defined by ASC 850 - Related Party Disclosures , as of and for the six months ended June 30, 2018 and 2017 and the outstanding balances as of June 30, 2018 and December 31, 2017. Balances associated with our investments in unconsolidated affiliates are disclosed in Note 10 - Investments in unconsolidated affiliates. Blackwater Midstream Holdings, LLC In December 2013, we acquired Blackwater Midstream Holdings, LLC (“Blackwater”) from an affiliate of ArcLight. The acquisition agreement included a provision whereby an ArcLight affiliate would be entitled to an additional $5.0 million of merger consideration based on Blackwater meeting certain operating targets. At June 30, 2018, we have $5.0 million accrued to the ArcLight affiliate which is included in Accrued expense and other current liabilities in the accompanying Condensed Consolidated Balance Sheets. Final resolution of the merger consideration will be determined in the third quarter of 2018 in connection with the sale of Marine Products. Republic Midstream, LLC Republic Midstream, LLC (“Republic”), is an entity owned by ArcLight to which we historically charged a monthly fee of approximately $0.1 million . The services agreement with Republic terminated according to its terms in September 2017 and services are no longer provided to Republic. As of June 30, 2018, and December 31, 2017, we had an accounts receivable balance due from Republic of $0.1 million and $0.8 million , respectively, which is included in Other current assets in the accompanying Condensed Consolidated Balance Sheets. General Partner During the first half of 2018, our General Partner paid $23.3 million related to Corporate overhead support which was presented as part of the contribution line item in Cash flows from financing activities in our Condensed Consolidated Statements of Cash Flows. As of June 30, 2018, and December 31, 2017, we had $5.2 million and $6.5 million , respectively, of accounts payable due to our General Partner, which has been recorded in Accrued expenses and other current liabilities and relates primarily to compensation. This payable/receivable is generally settled on a quarterly basis related to the foregoing transactions. On March 11, 2018, the Partnership and Magnolia, an affiliate of ArcLight, entered into a Capital Contribution Agreement (the “Capital Contribution Agreement”) to provide additional capital and overhead support to us during the first three quarters of 2018 in connection with temporary curtailment of production flows at Delta House. Pursuant to the Capital Contribution Agreement, Magnolia has agreed to provide quarterly capital contributions, in an amount to be agreed, up to the difference between the actual cash distribution received by us on account of our interest in Delta House and the quarterly cash distribution expected to be received had the production flows to Delta House not been curtailed. In accordance with this agreement, Magnolia agreed to a capital contribution of $9.4 million , which was paid in the second quarter of 2018. Subsequent to June 30, 2018, in accordance with this agreement, Magnolia agreed to a capital contribution of $8.3 million , which was paid in August 2018. Destin and Okeanos On November 1, 2016, we became operator of the Destin and Okeanos pipelines and entered into operating and administrative management agreements under which our 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 six months ended June 30, 2018, and 2017, we recognized $1.3 million and $1.2 million of management fee income, respectively, for each period. As of June 30, 2018, and December 31, 2017, we had an outstanding accounts receivable balance of $4.0 million and $0.9 million , respectively, which is included in Other current assets in the accompanying Condensed Consolidated Balance Sheets. Consolidated Asset Management Services, LLC ("CAMS") Dan Revers, a director of our General Partner, indirectly owns in excess of 10% of CAMS, which, through various subsidiaries or affiliates, provides pipeline integrity services to the Partnership and subleases an office space from the Partnership. During the six months ended June 30, 2018 and 2017, the Partnership was invoiced by CAMS $0.2 million for each respective period and had no outstanding accounts receivable balance as of June 30, 2018 or December 31, 2017. Other Related Party Transactions Michael D. Rupe, the brother of Ryan Rupe (the Partnership’s Vice President - Natural Gas Services and Offshore Pipelines), is the Chief Financial Officer of CIMA Energy Ltd., a crude oil and natural gas marketing company (“CIMA”). The Partnership regularly engages in purchases and sales of crude oil and natural gas with CIMA. During the six months ended June 30, 2018, the Partnership invoiced CIMA $1.1 million and received invoicing from CIMA of $2.7 million in connection with such transactions. For the six months ended June 30, 2017, the Partnership invoiced CIMA $2.5 million and received invoices from CIMA of $2.6 million for services. As of June 30, 2018, and December 31, 2017, the Partnership had $0.1 million outstanding amounts due to/from CIMA. During September and October 2017, under a transition services agreement, the Partnership made payments on behalf of AMID Merger GP II, LLC related to the Propane Business sale. As of June 30, 2018, and December 31, 2017, we had an outstanding accounts receivable balance related to these payments of $2.5 million which is included in Other current assets in the accompanying Condensed Consolidated Balance Sheets. For additional information on Related Parties, see Note 21 - Related Party Transactions , in our 2017 Form 10-K.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information (Notes)	6 Months Ended
	Jun. 30, 2018
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	(20) Supplemental Cash Flow Information Supplemental cash flows and non-cash transactions consist of the following (in thousands): Six months ended June 30, 2018 2017 Supplemental cash flow information Interest payments, net of capitalized interest $ 36,778 $ 27,324 Supplemental non-cash information Investing Increase (decrease) in accrued property, plant and equipment purchases (2,584 ) (3,131 ) Accrued contributions to unconsolidated affiliates (1,585 ) — Financing Contributions from an affiliate holding limited partner interests — 4,000 Accrued distributions on convertible preferred units 8,354 8,659 Paid-in-kind distributions on convertible preferred units 8,076 4,914

Reportable Segments

Reportable Segments	6 Months Ended
	Jun. 30, 2018
Segment Reporting [Abstract]
Reportable Segments	(21) Reportable Segments Our operations are organized into five reportable segments: (1) Gas Gathering and Processing Services, (2) Liquid Pipelines and Services, (3) Natural Gas Transportation Services, (4) Offshore Pipelines and Services, and (5) Terminalling Services. We disclose the results of each of our operating segments in accordance with ASC 280, Segment Reporting . Each of our operating segments is managed by a senior executive reporting directly to our Chief Executive Officer, the chief operating decision maker (“CODM”). Our Chief Executive Officer evaluates the performance of our reportable segments primarily on the basis of segment gross margin, which is our segment measure of profitability. Our chief operating decision maker uses gross margin as the primary measure for reviewing our segments’ profitability and therefore, in accordance with ASC 280, we have presented gross margin for each segment. For segments other than Terminalling Services, we define segment gross margin as (i) total revenue plus unconsolidated affiliate earnings less (ii) unrealized gains (losses) on commodity derivatives, construction and operating management agreement income, and the cost of sales. Gross margin for Terminalling Services also deducts direct operating expense, which includes direct labor, general materials and supplies and direct overhead. The following tables set forth our segment information for the three and six months ended June 30, 2018 and 2017 (in thousands): Three months ended June 30, 2018 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 49,509 $ 120,617 $ 15,567 $ 18,519 $ 16,360 $ 220,572 Gain (loss) on commodity derivatives, net (294 ) (61 ) — — — (355 ) Total revenue 49,215 120,556 15,567 18,519 16,360 220,217 Operating expenses: Cost of Sales 34,948 115,193 5,839 2,150 3,378 161,508 Direct operating expenses — — — — 4,131 21,742 Corporate expenses 23,372 Depreciation, amortization and accretion expense 21,236 Total operating expenses 227,858 Operating income (loss) (7,641 ) Other income (expense), net Interest expense, net of capitalized interest (19,691 ) Other income (expense), net 169 Earnings in unconsolidated affiliates — 2,485 — 7,961 — 10,446 Income (loss) from continuing operations before income taxes (16,717 ) Income tax expense (557 ) Loss from continuing operations (17,274 ) Less: Net income attributable to non-controlling interests 13 Net loss attributable to the Partnership $ (17,287 ) Segment gross margin $ 14,539 $ 7,744 $ 9,653 $ 24,330 $ 8,851 Three months ended June 30, 2017 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 39,307 $ 83,157 $ 11,397 $ 12,139 $ 15,831 $ 161,831 Gain (loss) on commodity derivatives, net (98 ) 297 — — — 199 Total revenue 39,209 83,454 11,397 12,139 15,831 162,030 Operating expenses: Cost of Sales 26,582 78,101 5,678 2,586 2,073 115,020 Direct operating expenses — — — — 2,998 18,709 Corporate expenses 27,374 Depreciation, amortization and accretion expense 26,483 Gain on sale of assets, net 18 Total operating expenses 187,604 Operating income (loss) (25,574 ) Other income (expenses), net Interest expense, net of capitalized interest (17,122 ) Earnings in unconsolidated affiliates — 1,482 — 16,070 — 17,552 Income (loss) from continuing operations before income taxes (25,144 ) Income tax expense (757 ) Loss from continuing operations (25,901 ) Loss from discontinued operations (1,801 ) Net loss (27,702 ) Less: Net income attributable to non-controlling interests 1,462 Net loss attributable to the Partnership $ (29,164 ) Segment gross margin $ 12,651 $ 6,765 $ 5,631 $ 25,623 $ 10,760 Six months ended June 30, 2018 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 85,185 $ 240,388 $ 31,629 $ 35,380 $ 33,758 — $ 426,340 Gain (loss) on commodity derivatives, net (292 ) (4 ) — — — — (296 ) Total revenue 84,893 240,384 31,629 35,380 33,758 426,044 Operating expenses: Cost of Sales 58,003 229,998 11,126 4,146 8,401 — 311,674 Direct operating expenses — — — — 8,453 — 45,189 Corporate expenses — 46,064 Depreciation, amortization and accretion expense 43,234 Gain on sale of assets, net (95 ) Total operating expenses 446,066 Operating income (loss) (20,022 ) Other income (expense), net Interest expense, net of capitalized interest (33,567 ) Other income (expense), net 191 Earnings in unconsolidated affiliates — 4,706 — 18,413 — — 23,119 Loss from continuing operations before income taxes (30,279 ) Income tax expense (837 ) Loss from continuing operations (31,116 ) Net loss (31,116 ) Less: Net income attributable to non-controlling interests — 57 Net loss attributable to the Partnership $ (31,173 ) — Segment gross margin $ 27,193 $ 15,014 $ 20,340 $ 49,647 $ 16,904 Six months ended June 30, 2017 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 73,714 $ 166,568 $ 23,835 $ 26,970 $ 34,457 $ 325,544 Gain (loss) on commodity derivatives, net (105 ) 669 — — — 564 Total revenue 73,609 167,237 23,835 26,970 34,457 326,108 Operating expenses: Cost of Sales 49,769 156,386 11,938 5,929 6,466 230,488 Direct operating expenses — — — — 6,071 36,114 Corporate expenses 57,487 Depreciation, amortization and accretion expense 52,053 Gain on sale of assets, net (3 ) Total operating expenses 376,139 Operating income (loss) (50,031 ) Other income (expenses), net Interest expense, net of capitalized interest (35,078 ) Other income (expense), net (37 ) Earnings in unconsolidated affiliates — 2,569 — 30,385 — 32,954 Loss from continuing operations before income taxes (52,192 ) Income tax expense (1,880 ) Loss from continuing operations (54,072 ) Loss from discontinued operations (2,511 ) Net loss (56,583 ) Less: Net income attributable to non-controlling interests 2,765 Net loss attributable to the Partnership $ (59,348 ) Segment gross margin $ 23,902 $ 13,401 $ 11,750 $ 51,426 $ 21,920 A reconciliation of total assets by segment to the amounts included in the Condensed Consolidated Balance Sheets follows (in thousands): June 30, December 31, 2018 2017 Segment assets: Gas Gathering and Processing Services $ 388,147 $ 404,872 Liquid Pipelines and Services 374,668 359,646 Offshore Pipelines and Services 521,710 553,213 Natural Gas Transportation Services 266,972 268,991 Terminalling Services 289,226 293,085 Other (1) 100,604 43,659 Total assets $ 1,941,327 $ 1,923,466 Investment in equity method investees: Liquid Pipelines and Services $ 68,357 $ 64,399 Offshore Pipelines and Services 263,173 284,035 Total Investment in equity method investees $ 331,530 $ 348,434 ________________________ (1) Other assets consists primarily of corporate assets not allocable to segments, such as leasehold improvements and other current assets. The following table sets forth capital expenditures for the three and six months ended June 30, 2018 and 2017 by segment (in thousands): Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 Capital expenditures Gas Gathering and Processing Services $ 6,657 $ 4,143 $ 13,311 $ 8,526 Liquid Pipelines and Services 4,767 1,005 11,180 1,376 Offshore Pipelines and Services 14,004 1,611 20,354 1,134 Natural Gas Transportation Services 1,154 14,138 2,492 24,366 Terminalling Services 2,416 1,031 6,122 2,841 Corporate 1,592 1,015 3,074 3,645 Total capital expenditures (1) $ 30,590 $ 22,943 $ 56,533 $ 41,888 _____________________________________ (1) Capital expenditures exclude expenditures made for the Propane Business of approximately $1.3 million and $ 2.2 million for the three and six months ended June 30, 2017, respectively, as the business was sold in 2017.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2018
Subsequent Events [Abstract]
Subsequent Events	(22) Subsequent Events Distribution On July 27, 2018, we announced that the Board of Directors of our general partner declared a quarterly cash distribution of $0.1031 per common unit, or $0.4125 per common unit annualized, with respect to the second quarter of 2018. The quarterly cash distribution, per common unit, for the second quarter of 2018 represents a reduction in the quarterly common unit distribution from prior quarters as part of our capital allocation strategy we announced in July 2018. The distribution will be paid on August 14, 2018 to unitholders of record as of the close of business on August 6, 2018 . Termination of Merger On July 29, 2018, we received notice of termination of the Agreement and Plan of Merger, dated as of October 31, 2017, from Southcross Energy Partners, L.P. and notice of termination of the Contribution Agreement, dated as of October 31, 2017, from Southcross Holdings LP. Under the terms of the Contribution Agreement, Southcross Holdings LP is entitled to receive a $17 million reverse termination fee. The termination fee serves as liquidated damages and was paid in August 2018. Marine Products Disposition On July 31, 2018, we completed the previously announced sale of our Marine Products. Net proceeds from this disposition were approximately $208.6 million , exclusive of $5.7 million in advisory fees and other costs, and were used to paydown the Credit Agreement. Termination of Sale On August 1, 2018, we and DKGP announced the termination of the sales agreement for the sale of our Refined Products. We are continuing to market the Refined Products terminals. See Note 4 - Acquisitions and Dispositions for additional information.

Organization and Basis of Pre31

Organization and Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization	Organization American Midstream Partners, LP (together with its consolidated subsidiaries, the “Partnership”, “we”, “us”, or “our”) is a growth-oriented Delaware limited partnership that was formed in August 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 77.0% directly owned by High Point Infrastructure Partners, LLC (“HPIP”) and 23.0% indirectly owned by Magnolia Infrastructure Holdings, LLC (“Magnolia”), 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. We provide critical midstream infrastructure that links producers of natural gas, crude oil, NGLs, condensate and specialty chemicals to numerous intermediate and end-use markets. Through our five reportable segments, (1) Gas Gathering and Processing Services, (2) Liquid Pipelines and Services, (3) Natural Gas Transportation Services, (4) Offshore Pipelines and Services, and (5) Terminalling Services, we engage in the business of gathering, treating, processing and transporting natural gas; gathering, transporting, storing, treating and fractionating NGLs; gathering, storing and transporting crude oil and condensates; and storing specialty chemical products 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.
Basis of Presentation	Basis of presentation The accompanying Condensed Consolidated Financial Statements are unaudited and have been prepared in accordance with Article 10 of Regulation S-X for interim financial information. Accordingly, they do not include all the information and notes required by GAAP for complete financial statements. In the opinion of our management, all adjustments, consisting only of normal recurring adjustments, considered necessary for a fair statement have been included. The results of operations for interim periods are not necessarily indicative of results of operations for a full year. These Condensed Consolidated Financial Statements should be read in conjunction with our Consolidated Financial Statements and Notes thereto included in our Annual Report on Form 10-K (“Annual Report”) for the year ended December 31, 2017 filed with the U.S. Securities and Exchange Commission (the “SEC”) on April 9, 2018 (the “2017 Form 10-K”). On April 15, 2013, ArcLight affiliates obtained control of our General Partner. We account for transactions between entities under common control at the affiliate's historical costs. For those transactions, our historical financial statements will be revised to include the results attributable to the assets acquired as if they were acquired on April 15, 2013 or the date the ArcLight affiliates obtained control of the assets or business acquired.
New Accounting Pronouncements	Standards Adopted in 2018 Revenue from Contracts with Customers (Topic 606 ) - In May 2014, the Financial Accounting Standards Board (the “FASB”) issued a new standard related to revenue recognition which supersedes most of the existing revenue recognition requirements in GAAP and requires entities to recognize revenue at an amount that reflects the consideration to which an entity expects to be entitled in exchange for transferring goods or services to a customer. It also requires significantly expanded disclosures regarding the qualitative and quantitative information of an entity’s nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The FASB has issued several amendments to the standard, including clarification on accounting for licenses of intellectual property, identifying performance obligations, reporting gross versus net revenue and narrow-scope revisions and practical expedients. We adopted the new standard on January 1, 2018 (the “initial application” date): • using the modified retrospective application, with no restatement of the comparative periods presented and a cumulative effect adjustment to retained earnings as of the date of adoption; and • disclosing the impact of the new standard in our Condensed Consolidated Financial Statements included in this report. Our revenue is derived from the provision of gathering, processing, transportation, terminalling and storage services and the sale of commodities primarily to marketers and brokers, refiners and chemical manufacturers, utilities and power generation customers, industrial users, and local distribution companies. Beginning on January 1, 2018, we account for revenue from contracts with customers in accordance with Topic 606. The unit of account in Topic 606 is a performance obligation, which is a promise in a contract to transfer to a customer either a distinct good or service (or bundle of goods or services) or a series of distinct goods or services provided at a point in time or over a period of time. Topic 606 requires that a contract’s transaction price, which is the amount of consideration to which an entity expects to be entitled in exchange for transferring promised goods or services to a customer, is to be allocated to each performance obligation in the contract based on relative standalone selling prices and recognized as revenue when (point in time) or as (over time) the performance obligation is satisfied. Commodity Sales - For the majority of our commodity sales contracts: (i) each unit of product is a separate performance obligation, since our promise is to sell multiple distinct units of product at a point in time; (ii) the transaction price principally consists of variable consideration, which is determinable on commodity index prices for the volume of the product sold to the customer that month; and (iii) the transaction price is allocated to each performance obligation based on the product’s standalone selling price. Revenues from sales of commodities are recognized at the point in time when control of the commodity transfers to the customer, which generally occurs upon delivery of the product to the customer or its designee. Payment is generally received from the customer in the month following delivery. Contracts with customers have varying terms, including spot sales, month-to-month contracts and multi-year agreements. In our Liquid Pipelines and Services segment, we enter into purchase and sales contracts as well as buy/sell contracts with counterparties, under which we gather and transport different types of crude oil and eventually sell the crude oil to either the same counterparty or different counterparties. For each of these arrangements, the Partnership assesses if control of the underlying commodity volumes transfer to the Partnership. Generally, the Partnership is unable to direct the use of the commodity volumes it purchases from the supplier because the Partnership is contractually required to redeliver an equivalent volume of the commodity back to the supplier or to a specified customer therefore, these arrangements are recorded on a net basis. Occasionally, we enter into crude oil inventory exchange arrangements with the same counterparty where the purchase and sale of inventory are considered in contemplation of each other. These types of arrangements are accounted for as inventory exchanges and are recorded on a net basis. Services - The Partnership provides gathering, processing, transportation, terminalling and storage services pursuant to a variety of contracts. Generally, for the majority of these contracts: (i) our promise is to transfer (or stand ready to transfer) a series of distinct integrated services over a period of time, which is a single performance obligation and (ii) the transaction price includes fixed or variable consideration, or both fixed and variable consideration. The amount of consideration is determinable at contract inception or at each month’s end based on our right to invoice at month end for the value of services provided to the customer in that month. Revenue is recognized over the service period specified in the contract as the services are rendered using a time-based (passage of time) or units-based (units of service transferred) method for measuring provision of the services. Progress towards satisfying our performance obligation is based on the firm or interruptible nature of the promised service and the terms and conditions of the contract (such as contracts with or without makeup rights). Payment is generally received from the customer in the month of service or the month following the service. Contracts with customers generally are a combination of month-to-month and multi-year agreements. Firm Services - Firm services are services that are promised to be available to the customer at all times during the term of the contract, with limited exceptions. These agreements require customers to deliver, transport or throughput a minimum volume over an agreed upon period. Substantially all of such agreements are entered into with customers to economically support the return on our capital expenditure necessary to construct the related asset. Our firm service contracts are typically structured with take-or-pay or minimum volume provisions, which specify minimum service quantities a customer will pay for even if it chooses not to receive or use them in the specified service period (referred to as “deficiency quantities”). Under firm service contracts, we record a receivable from the customer in the period that services are provided or when the transaction occurs, including amounts for deficiency quantities from customers associated with minimum volume commitments. If a customer has a make-up right associated with a deficiency, we defer the revenue attributable to the counterparty’s make-up right and subsequently recognize the revenue at the earlier of when the deficiency volume is delivered or shipped, when the make-up right expires or when it is determined that the customer’s ability to utilize the make-up right is remote. Interruptible Services - Interruptible services are services provided to the extent that we have available capacity. Generally, we do not have an obligation to perform these services until we accept a customer’s periodic request for service. For the majority of these contracts, the customer will pay only for the actual quantities of services it chooses to receive or use, and we typically recognize the transaction price as revenue as those units of service are transferred to the customer in the specified service period. Gathering and Processing - 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. Services can be firm if subject to a minimum volume commitment or acreage dedication or interruptible when offered on an as requested, non-guaranteed basis. Revenue for fee-based gathering and processing services are valued based on the rate in effect for the month of service and is recognized in the month of service based on the volumes of natural gas we gather, process and fractionate. Under these arrangements, we may take control of: (i) none of the commodities we sell (i.e., residue gas or NGLs), (ii) a portion of the commodities we sell, or (iii) all of the commodities we sell. In those instances where we purchase and obtain control of the entire natural gas stream in our producer arrangements, we have determined these are contracts with suppliers rather than contracts with customers and therefore, these arrangements are not included in the scope of Topic 606. These supplier arrangements are subject to updated guidance in Accounting Standards Codification (“ASC”) 705, “ Cost of Sales and Services ,” whereby any embedded fees within such contracts, which historically have been reported as services revenue, are now reported as a reduction to cost of sales upon adoption of Topic 606. In those instances where we remit all of the cash proceeds received from third parties for selling the extracted commodities to the producer, less the fees attributable to these arrangements, we have determined that the producer has control over these commodities. Upon adoption of Topic 606, we eliminated recording both sales revenue (natural gas and products) and cost of sales amounts and now only record fees attributable to these arrangements as service revenues. In other instances where we do not obtain control of the extracted commodities we sell, we are acting as an agent for the producer and, upon adoption of Topic 606, we have continued to recognize services revenue for the net amount of consideration we retain in exchange for our service. The Partnership may charge additional service fees to customers for a portion of the contract term (i.e., for the first year of a contract or until reaching a volume threshold) due to the significant upfront capital investment, and these fees are initially deferred and recognized to revenue over the expected period of customer benefit, generally the lesser of the expected contract term or the life of the related properties. Transportation - Our transportation operations generally consist of fee-based activities associated with transporting crude oil, natural gas, and NGL on pipelines, gathering systems and trucks. Revenues from pipeline tariffs and fees are associated with the transportation at a published tariff, as well as revenues associated with agreements for committed capacity on various assets. We primarily recognize pipeline tariff and fee revenues over time based on the volumes delivered and invoiced. The majority of our pipeline tariff and fee revenues are based on actual volumes and rates. As is common in the pipeline transportation industry, our tariffs incorporate a loss allowance factor. The intent of the allowance in arrangements for the transportation of natural gas is to approximate the natural shrink that occurs when transporting the gas. For crude oil transportation arrangements, loss allowance provisions are immaterial to the Partnership. In the event the Partnership retains excess natural gas and crude oil and subsequently sells the commodity to a third party, the sale is recorded at that point in time as a commodity sale. Terminalling and Storage - In our Terminalling Services segment, we generally receive fee-based compensation on guaranteed firm storage contracts, throughput fees charged to our customers when their products are either received or disbursed, and other operational charges associated with ancillary services provided to our customers, such as excess throughput, steam heating and truck weighing at our marine terminals. Storage fees resulting from short-term and long-term contracts are typically recognized in revenue ratably over the term of the contract regardless of the actual storage capacity utilized. Adoption of the new revenue standard resulted in changes to the timing of revenue recognition and in the reclassification between financial statement line items. See Note 3 - Revenue Recognition , for further discussion . Statement of Cash Flows - In August 2016, the FASB issued Accounting Standards Update (“ASU”) No. 2016-15, “ Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments ” (“ASU 2016-15”). ASU 2016-15 provides specific guidance on cash flow classification issues to reduce diversity in practice. There was no impact of the retrospective adoption of this ASU on the Partnership’s Condensed Consolidated Statements of Cash Flows. In November 2016, the FASB issued ASU No. 2016-18, “ Statement of Cash Flows (Topic 230): Restricted Cash ”(“ASU 2016-18”), which requires amounts described as restricted cash and restricted cash equivalents to be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. A reconciliation between the balance sheet and the statement of cash flows must be disclosed when the balance sheet includes more than one-line item for cash, cash equivalents, restricted cash and restricted cash equivalents. We retrospectively adopted ASU 2016-15 and ASU 2016-18 as of January 1, 2018. Previously reported financial statements have been adjusted to reflect the above changes, as follows (in thousands): Six months ended June 30, 2017 Condensed Consolidated Statements of Cash Flows As Previously Reported Effect of Adoption As Adjusted Cash flows from operating activities Net loss $ (56,583 ) $ — $ (56,583 ) Adjustments to reconcile net loss to net cash provided by operating activities including discontinued operations 78,200 — 78,200 Restricted cash, short-term (3,135 ) (1 ) 3,135 (1 ) — Changes in operating assets and liabilities, net of effects of assets acquired and liabilities assumed (excluding restricted cash) 6,794 (1 ) (53 ) (1 ) 6,741 Net cash provided by (used in) operating activities 25,276 3,082 28,358 Cash flows from investing activities Restricted cash 302,643 (1 ) (302,643 ) (1 ) — Other investing activities (excluding restricted cash) (70,328 ) — (70,328 ) Net cash provided by (used in) investing activities 232,315 (302,643 ) (70,328 ) Cash flows from financing activities Other financing activities (257,354 ) — (257,354 ) Net cash used in financing activities (excluding restricted cash) (257,354 ) — (257,354 ) Net increase (decrease) in cash, cash equivalents, and restricted cash 237 (299,561 ) (299,324 ) Cash, cash equivalents and Restricted Cash Beginning of period 5,666 323,564 329,230 End of period $ 5,903 $ 24,003 $ 29,906 _____________________________________________ (1) ASU 2016-18 adjustment to move restricted cash to be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the condensed consolidated statement of cash flows. Stock Compensation - In May 2017, the FASB issued ASU No. 2017-09, “ Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting ” (“ASU 2017-09”). ASU 2017-09 was issued with the intent to clarify the scope of modification accounting and when it should be applied to a change to the terms or conditions of a share-based payment award. Under the new guidance, modification accounting is required for all changes to share based payment awards, unless all the following conditions are met: (i) there is no change to the fair value of the award, (ii) the vesting conditions have not changed, and (iii) the classification of the award as an equity instrument or a debt instrument has not changed. We adopted ASU 2017-09 on its effective date of January 1, 2018, and the adoption did not have a material impact on our Condensed Consolidated Financial Statements. Income Taxes - In March 2018, the FASB issued ASU No. 2018-05, “ Income Taxes (Topic 740): Amendments to SEC Paragraphs Pursuant to SEC Staff Accounting Bulletin No. 118 (SEC Update) ”(“ASU 2018-05”), to provide guidance for companies that have not completed their accounting for the income tax effects of the Tax Cuts and Jobs Act (the “Act”) in the period of enactment. The measurement period begins in the reporting period that includes the Act’s enactment date of December 22, 2017, and ends when a company has obtained, prepared and analyzed the information needed to complete the accounting requirements under ASU 2018-05 and should not extend beyond one year from the enactment date. The impact of adopting the new guidance on our consolidated financial position, cash flows or results of operations, as well as on related disclosures was not material. Standards Not Yet Adopted Leases (Topic 842) - In February 2016, the FASB issued ASU No. 2016-02 (“Topic 842”) “ Leases ”, which supersedes the lease recognition requirements in ASC Topic 840, “Leases”. Under the new guidance, for leases with a term longer than 12 months a lessee should recognize a lease liability and a right-of-use asset representing its right to use the underlying asset for the lease term. Topic 842 retains a classification distinction between finance leases and operating leases, with the classification affecting the pattern of expense recognition in the income statement. This ASU also requires enhanced disclosures. Early adoption is permitted. We are currently assessing the impact of this new guidance via review of existing contracts that may have a lease impact and other purchase obligations that contain embedded lease features, which are generally classified as operating leases under the existing guidance. We selected a third-party consulting firm to assist us with the adoption of the new guidance. We intend to complete any required changes to our systems, software applications and processes, including updating our internal controls during 2018. In 2018, the FASB also issued ASU No. 2018-01, “Land Easement Practical Expedient for Transition to Topic 842” and ASU No. 2018-11, “Targeted Improvements”. Under these updates, optional transition practical expedients are available i) whereby existing or expired land easements that were not previously accounted for as leases under Topic 840 are not required to be evaluated under Topic 842, and ii) lease and associated non-lease components are not required to be separated within a contract if certain criteria are met. In addition, under ASU No. 2018-11, companies may initially apply the new lease requirements at the effective date. We intend apply the new lease requirements as of January 1, 2019, recognizing a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption, and to apply the practical expedients. Financial Instruments - In June 2016, the FASB issued ASU No. 2016-13 (“ASU 2016-13”), “ Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments” . This guidance will become effective for interim and annual periods beginning after December 15, 2019. We expect to adopt ASU 2016-13 on January 1, 2020, and we are currently evaluating the effect that adopting this guidance will have on our consolidated financial position, results of operations and cash flows. Critical Accounting Policies and Estimates See Item 7 Section Critical Accounting Policies and Estimates and Item 1A. Risk Factors of the 2017 Form 10-K for additional information relating to our critical accounting policies and risk factors. Goodwill - We record goodwill for the excess of the cost of an acquisition over the fair value of the net assets of the acquired business. Goodwill is reviewed for impairment at least annually or more frequently if an event or change in circumstance indicates that an impairment may have occurred. We first assess qualitative factors to evaluate whether it is more likely than not that an impairment has occurred, and it is therefore necessary to perform the one-step quantitative goodwill impairment test. If the one-step quantitative goodwill impairment test indicates that the goodwill is impaired, an impairment loss is recorded, which is the difference between carrying value of the reporting unit and its fair value, with the impairment loss not to exceed the amount of goodwill recorded. When performing a quantitative impairment test, the Partnership generally determines the fair value of its reporting units using a discounted cash flow method. In the event the Partnership enters into an agreement to sell all or substantially all of a reporting unit, the Partnership will utilize such information. While using the discounted cash flow method, we must make estimates of projected cash flows related to assets, which include, but are not limited to, assumptions about revenue growth rates, operating margins, weighted average costs of capital and future market conditions, the use or disposition of assets, estimated remaining life of assets, and future expenditures necessary to maintain current operations. We also must make certain estimates and assumptions, including, among other things, changes in general economic conditions in regions in which our markets are located, the availability and prices of energy commodities (such as natural gas, crude oil and refined products), our ability to negotiate favorable sales agreements, the risks that natural gas exploration and production activities will not occur or be successful, our dependence on certain significant customers and producers of natural gas, and competition from other companies. Under the discounted cash flow method, the Partnership determines fair value based on estimated future cash flows and earnings before income tax, depreciation and amortization (“EBITDA”) of each reporting unit including estimates for capital expenditures, discounted to present value using the risk-adjusted industry rate, which reflects the overall level of inherent risk of the reporting unit. Cash flow projections are derived from one-year budgeted amounts and five-year operating forecasts plus an estimate of later period cash flows, all of which are evaluated by management. Subsequent period cash flows are developed for each reporting unit using growth rates that management believes are reasonably likely to occur. The annual budget process is typically completed near the annual goodwill impairment testing date, and management uses the most recent information for the annual impairment tests. The forecast is also subjected to a comprehensive update annually in conjunction with the annual budget process and is revised periodically to reflect new information and revised expectations. The estimates of future cash flows and EBITDA are subjective in nature and are subject to impacts from the business risks described in “Item 1A. Risk Factors” of the 2017 Form 10-K. While we believe we have made reasonable estimates and assumptions based on available information to calculate the fair value, if future results are not consistent with our estimates, changes in fair value estimates could result in additional impairments in future periods that could be material to our results of operations. As of December 31, 2017, the Partnership had approximately $128.9 million of goodwill on its consolidated balance sheet within seven reporting units. Of this amount, approximately $46.8 million of goodwill in two reporting units was at risk of failing the one-step quantitative test. Specifically, the Silver Dollar reporting unit in the Liquids Pipelines and Services segment had $35.7 million in goodwill. As described in Note 10 in our 2017 Form 10-K, we recorded an impairment on the Silver Dollar Reporting unit during the fourth quarter of 2017; hence, fair value approximates the adjusted net book value subsequent to impairment. The 2017 impairment related primarily to cash flow assumptions included in our discounted cash flow analysis that were adversely impacted by delays in drilling and completions experienced by producers. The Cushing reporting unit in the Terminalling Services segment had $11.1 million in goodwill as of December 31, 2017, and fair value exceeded book value by 7% . In our discounted cash flow analysis for 2017, we assumed lower utilization rates and cash flows due to required tank inspections through early 2019. The lower utilization was not previously expected in our assumptions. If the expected completion date of the inspections or future contracting rates should differ from the assumptions made in our 2017 analysis, the amount by which fair value exceeds book value could be negatively impacted. As of June 30, 2018, the Partnership had approximately $51.7 million of goodwill on its consolidated balance sheet within five reporting units as two of the seven reporting units, as of December 31, 2017, are now classified as held for sale. There were no triggering events during the six months ended June 30, 2018 and, therefore, we have not quantitatively updated our assessments.

New Accounting Pronouncements (

New Accounting Pronouncements (Tables)	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
Impact of New Accounting Pronouncements	Six months ended June 30, 2017 Condensed Consolidated Statements of Cash Flows As Previously Reported Effect of Adoption As Adjusted Cash flows from operating activities Net loss $ (56,583 ) $ — $ (56,583 ) Adjustments to reconcile net loss to net cash provided by operating activities including discontinued operations 78,200 — 78,200 Restricted cash, short-term (3,135 ) (1 ) 3,135 (1 ) — Changes in operating assets and liabilities, net of effects of assets acquired and liabilities assumed (excluding restricted cash) 6,794 (1 ) (53 ) (1 ) 6,741 Net cash provided by (used in) operating activities 25,276 3,082 28,358 Cash flows from investing activities Restricted cash 302,643 (1 ) (302,643 ) (1 ) — Other investing activities (excluding restricted cash) (70,328 ) — (70,328 ) Net cash provided by (used in) investing activities 232,315 (302,643 ) (70,328 ) Cash flows from financing activities Other financing activities (257,354 ) — (257,354 ) Net cash used in financing activities (excluding restricted cash) (257,354 ) — (257,354 ) Net increase (decrease) in cash, cash equivalents, and restricted cash 237 (299,561 ) (299,324 ) Cash, cash equivalents and Restricted Cash Beginning of period 5,666 323,564 329,230 End of period $ 5,903 $ 24,003 $ 29,906 _____________________________________________ (1) ASU 2016-18 adjustment to move restricted cash to be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the condensed consolidated statement of cash flows. The effect of adopting Topic 606 due to the change in method to measure project progress, as discussed in Note 2 - Recent Accounting Pronouncements, is as follows (in thousands): Three months ended June 30, 2018 Six months ended June 30, 2018 Condensed Consolidated Statements of Operations As Reported Adjustments Amounts without Adoption of Topic 606 As Reported Adjustments Amounts without Adoption of Topic 606 Revenue Commodity sales $ 164,737 $ 12,535 $ 177,272 $ 323,599 $ 17,777 $ 341,376 Services 55,835 (12,304 ) 43,531 102,741 (14,985 ) 87,756 Operating expenses Costs of sales 161,508 5,409 166,917 311,674 8,574 320,248 Direct operating expenses 21,742 (4,550 ) 17,192 45,189 (5,006 ) 40,183 Operating loss (7,641 ) (628 ) (8,269 ) (20,022 ) (776 ) (20,798 ) Net loss attributable to the Partnership (17,287 ) (628 ) (17,915 ) (31,173 ) (776 ) (31,949 ) General Partner’s interest in net loss (225 ) (8 ) (233 ) (405 ) (10 ) (415 ) Limited Partners’ interest in net loss (17,062 ) (620 ) (17,682 ) (30,768 ) (766 ) (31,534 ) As of June 30, 2018 Condensed Consolidated Balance Sheets As Reported Adjustments Amounts without Adoption of Topic 606 Assets Accounts receivable, net $ 88,352 $ (76,684 ) $ 11,668 Unbilled revenue — 76,684 76,684 Other current assets 30,570 (252 ) 30,318 Other assets, net 27,984 (6,984 ) 21,000 Liabilities Other long-term liabilities 15,426 (13,865 ) 1,561 Liabilities held for sale 2,237 (690 ) 1,547

Revenue Recognition (Tables)

Revenue Recognition (Tables)	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
Impact of New Accounting Pronouncements	Six months ended June 30, 2017 Condensed Consolidated Statements of Cash Flows As Previously Reported Effect of Adoption As Adjusted Cash flows from operating activities Net loss $ (56,583 ) $ — $ (56,583 ) Adjustments to reconcile net loss to net cash provided by operating activities including discontinued operations 78,200 — 78,200 Restricted cash, short-term (3,135 ) (1 ) 3,135 (1 ) — Changes in operating assets and liabilities, net of effects of assets acquired and liabilities assumed (excluding restricted cash) 6,794 (1 ) (53 ) (1 ) 6,741 Net cash provided by (used in) operating activities 25,276 3,082 28,358 Cash flows from investing activities Restricted cash 302,643 (1 ) (302,643 ) (1 ) — Other investing activities (excluding restricted cash) (70,328 ) — (70,328 ) Net cash provided by (used in) investing activities 232,315 (302,643 ) (70,328 ) Cash flows from financing activities Other financing activities (257,354 ) — (257,354 ) Net cash used in financing activities (excluding restricted cash) (257,354 ) — (257,354 ) Net increase (decrease) in cash, cash equivalents, and restricted cash 237 (299,561 ) (299,324 ) Cash, cash equivalents and Restricted Cash Beginning of period 5,666 323,564 329,230 End of period $ 5,903 $ 24,003 $ 29,906 _____________________________________________ (1) ASU 2016-18 adjustment to move restricted cash to be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the condensed consolidated statement of cash flows. The effect of adopting Topic 606 due to the change in method to measure project progress, as discussed in Note 2 - Recent Accounting Pronouncements, is as follows (in thousands): Three months ended June 30, 2018 Six months ended June 30, 2018 Condensed Consolidated Statements of Operations As Reported Adjustments Amounts without Adoption of Topic 606 As Reported Adjustments Amounts without Adoption of Topic 606 Revenue Commodity sales $ 164,737 $ 12,535 $ 177,272 $ 323,599 $ 17,777 $ 341,376 Services 55,835 (12,304 ) 43,531 102,741 (14,985 ) 87,756 Operating expenses Costs of sales 161,508 5,409 166,917 311,674 8,574 320,248 Direct operating expenses 21,742 (4,550 ) 17,192 45,189 (5,006 ) 40,183 Operating loss (7,641 ) (628 ) (8,269 ) (20,022 ) (776 ) (20,798 ) Net loss attributable to the Partnership (17,287 ) (628 ) (17,915 ) (31,173 ) (776 ) (31,949 ) General Partner’s interest in net loss (225 ) (8 ) (233 ) (405 ) (10 ) (415 ) Limited Partners’ interest in net loss (17,062 ) (620 ) (17,682 ) (30,768 ) (766 ) (31,534 ) As of June 30, 2018 Condensed Consolidated Balance Sheets As Reported Adjustments Amounts without Adoption of Topic 606 Assets Accounts receivable, net $ 88,352 $ (76,684 ) $ 11,668 Unbilled revenue — 76,684 76,684 Other current assets 30,570 (252 ) 30,318 Other assets, net 27,984 (6,984 ) 21,000 Liabilities Other long-term liabilities 15,426 (13,865 ) 1,561 Liabilities held for sale 2,237 (690 ) 1,547
Disaggregation of Revenue	The following table presents the reconciliation of our revenues from contracts with customers to segment revenues and total revenues as disclosed in our Condensed Consolidated Statements of Operations (in thousands): Three months ended June 30, 2018 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenues from contracts with customers $ 49,509 $ 120,617 $ 15,567 $ 18,519 $ 16,360 $ 220,572 Loss on commodity derivatives, net (294 ) (61 ) — — — (355 ) Total revenues of reportable segments $ 49,215 $ 120,556 $ 15,567 $ 18,519 $ 16,360 $ 220,217 Six months ended June 30, 2018 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenues from contracts with customers $ 85,185 $ 240,388 $ 31,629 $ 35,380 $ 33,758 $ 426,340 Loss on commodity derivatives, net (292 ) (4 ) — — — (296 ) Total revenues of reportable segments $ 84,893 $ 240,384 $ 31,629 $ 35,380 $ 33,758 $ 426,044 The following table presents our segment revenues from contracts with customers disaggregated by type of activity (in thousands): Three months ended June 30, 2018 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Commodity sales: Natural gas $ 3,521 $ — $ 5,473 $ 2,587 $ — $ 11,581 NGLs 18,059 — — 33 — 18,092 Condensate 14,154 — — 63 — 14,217 Crude oil — 116,516 — — — 116,516 Other sales (1) 635 — 2 24 3,670 4,331 Services: Gathering and processing 12,463 — — 1,408 — 13,871 Transportation 143 3,626 9,857 10,229 — 23,855 Terminalling and storage — — — — 12,150 12,150 Other services (2) 534 475 235 4,175 540 5,959 Revenues from contracts with customers $ 49,509 $ 120,617 $ 15,567 $ 18,519 $ 16,360 $ 220,572 Six months ended June 30, 2018 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Commodity sales: Natural gas $ 5,427 $ — $ 12,110 $ 5,024 $ — $ 22,561 NGLs 39,209 — — 71 — 39,280 Condensate 19,802 — — 97 — 19,899 Crude oil — 232,297 — — — 232,297 Other sales (1) 818 — 6 64 8,674 9,562 Services: Gathering and processing 18,713 — — 2,274 — 20,987 Transportation 248 7,214 19,269 18,890 — 45,621 Terminalling and storage — — — — 23,983 23,983 Other services (2) 968 877 244 8,960 1,101 12,150 Revenues from contracts with customers $ 85,185 $ 240,388 $ 31,629 $ 35,380 $ 33,758 $ 426,340 _________________________ (1) Other commodity sales for our Terminalling Services segment include sales of Refined Products and Marine Products terminals. See Note 4 - Acquisitions and Dispositions. (2) Other services in our Offshore Pipelines and Services segment include asset management services.
Contract Balances	The following table presents the change in the contract assets and liability balances during the six months ended June 30, 2018 (in thousands): Contract Assets Contract Liabilities Balance at December 31, 2017 $ — $ 2,136 Topic 606 implementation 2,555 13,246 Amounts recognized as revenue — (1,463 ) Additions 4,681 2,661 Contract balances included in assets/liabilities held for sale — (690 ) Balance at June 30, 2018 $ 7,236 $ 15,890 Current $ 252 $ 1,194 Noncurrent 6,984 14,696 Balance at June 30, 2018 $ 7,236 $ 15,890
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	The following table as of June 30, 2018, represents only revenue expected to be recognized from contracts where the price and quantity of the product or service are fixed: Remainder of 2018 2019 2020 2021 2022 Thereafter Total Gathering and processing based on minimum volume commitments $ 6,165 $ 12,738 $ 12,738 $ 12,715 $ 12,461 $ 19,116 $ 75,933 Transportation agreements 11,232 20,163 19,225 19,029 18,943 193,731 282,323 Terminalling and storage throughput agreements 7,070 12,896 6,204 2,694 1,582 — 30,446 Other 846 1,648 1,560 — — — 4,054 Total (1) $ 25,313 $ 47,445 $ 39,727 $ 34,438 $ 32,986 $ 212,847 $ 392,756 _________________________ (1) Includes consideration for remaining performance obligations associated with assets held-for-sale .

Acquisitions and Dispositions (

Acquisitions and Dispositions (Tables)	6 Months Ended
	Jun. 30, 2018
Discontinued Operations and Disposal Groups [Abstract]
Disposal groups and discontinued operations	Summarized financial information related to the Propane Business is set forth in the tables below (in thousands): Three months ended June 30, Six months ended June 30, 2017 2017 Total revenue $ 31,603 $ 67,157 Total operating expenses 33,402 69,707 Operating loss (1,799 ) (2,550 ) Other income 42 83 Income tax expense (44 ) (44 ) Loss from discontinued operations $ (1,801 ) $ (2,511 ) Depreciation and amortization $ 3,687 $ 7,468 Capital expenditures $ 1,302 $ 2,421 Operating non-cash items Unrealized loss on derivative contracts, net $ (60 ) $ (961 ) Included in the disposal groups are the following assets and liabilities at June 30, 2018 (in thousands): Refined Products Marine Products Business (1) Business (2) Total Cash and cash equivalents $ — $ 364 $ 364 Accounts receivable, net 1,834 2,521 4,355 Inventory 506 31 537 Other current assets 213 144 357 Property, plant and equipment, net 32,332 84,661 116,993 Goodwill 61,163 16,262 77,425 Intangible assets 29,403 — 29,403 Other non-current assets 692 3 695 Total assets held for sale $ 126,143 $ 103,986 $ 230,129 Accounts payable $ 44 $ 152 $ 196 Accrued gas purchases 72 — 72 Accrued expenses and other current liabilities 991 406 1,397 Other long-term liabilities 572 — 572 Total liabilities held for sale $ 1,679 $ 558 $ 2,237 _________________________ (1) Net income from continuing operations before income taxes for the Refined Products Business were as follows: • $4.3 million and $1.6 million for the three months ended June 30, 2018 and 2017, respectively; and • $6.7 million and $3.4 million for the six months ended June 30, 2018 and 2017, respectively. (2) Net income from continuing operations before income taxes for the Marine Products Business were as follows: • $3.5 million and $2.5 million for the three months ended June 30, 2018 and 2017, respectively; and • $5.1 million and $5.2 million for the six months ended June 30, 2018 and 2017, respectively.

Inventory (Tables)

Inventory (Tables)	6 Months Ended
	Jun. 30, 2018
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventory consists of the following (in thousands): June 30, 2018 December 31, 2017 Crude oil $ 2,184 $ 1,553 NGLs 357 347 Refined products — 934 Materials, supplies and equipment 120 132 Total inventory $ 2,661 $ 2,966

Other Current Assets (Tables)

Other Current Assets (Tables)	6 Months Ended
	Jun. 30, 2018
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of Other Current Assets	Other current assets consist of the following (in thousands): June 30, 2018 December 31, 2017 Prepaid expenses $ 7,196 $ 8,944 Insurance receivables 881 1,741 Due from related parties 6,773 4,362 Other receivables 8,801 5,187 Risk management assets 6,919 3,186 Total other current assets $ 30,570 $ 23,420

Risk Management Activities (Tab

Risk Management Activities (Tables)	6 Months Ended
	Jun. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of notional amounts of outstanding derivative positions	The following table summarizes the net notional volumes of our outstanding commodity-related derivatives, excluding those contracts that qualified for the NPNS exception as of June 30, 2018 and December 31, 2017 , none of which were designated as hedges for accounting purposes. June 30, 2018 December 31, 2017 Commodity Swaps Volume Maturity Volume Maturity NGLs Fixed Price (gallons) 2,188,200 January 2019 — —
Fair value associated with commodity derivative instruments	The following table summarizes the fair values of our derivative contracts (before netting adjustments) included in the Condensed Consolidated Balance Sheets (in thousands): Asset Derivatives Liability Derivatives Type Balance Sheet Classification June 30, December 31, 2017 June 30, December 31, 2017 Commodity derivatives Accrued expenses and other current liabilities $ — $ — $ (240 ) $ — Interest rate swaps Other current assets 5,970 2,677 — — Interest rate swaps Other assets net 11,605 8,807 — — Weather derivatives Other current assets 949 509 — — Total $ 18,524 $ 11,993 $ (240 ) $ —
Realized and unrealized gains (losses) with commodity and interest rate derivative instruments	For each of the three and six months ended June 30, 2018 and 2017 , the realized and unrealized gains (losses) associated with our commodity, interest rate and weather derivative instruments were recorded in our Condensed Consolidated Statements of Operations as follows (in thousands): Three months ended June 30, Six months ended June 30, Statement of Operations Classification Realized Unrealized Realized Unrealized 2018 Loss on commodity derivatives, net $ (174 ) $ (181 ) $ (56 ) $ (240 ) Interest expense 1,285 920 2,635 6,091 Direct operating expenses (272 ) — (550 ) — Total gain on derivatives recognized in net loss $ 839 $ 739 $ 2,029 $ 5,851 2017 Gains (losses) on commodity derivatives, net $ 192 $ 7 $ 613 $ (49 ) Interest expense — (1,693 ) (70 ) (2,010 ) Direct operating expenses (218 ) — (475 ) — Total (loss) gain on derivatives recognized in net loss $ (26 ) $ (1,686 ) $ 68 $ (2,059 )
Schedule of financial instruments not measured at fair value on a recurring basis	The following table presents the carrying value and estimated fair value of our financial instruments that are not measured at fair value on a recurring basis as of June 30, 2018 and December 31, 2017. Short-term and long-term debt are recorded at amortized cost in the Condensed Consolidated Balance Sheets. June 30, 2018 December 31, 2017 Carrying Amount Fair Value Carrying Amount Fair Value Non-Derivatives Liabilities 8.5% Senior Unsecured Notes $ 418,537 $ 420,137 $ 418,421 $ 437,062 3.77% Senior Secured Notes 55,447 50,822 56,005 53,845 3.97% Trans-Union Secured Senior Notes 30,824 28,053 31,692 30,221 Total $ 504,808 $ 499,012 $ 506,118 $ 521,128

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	6 Months Ended
	Jun. 30, 2018
Property, Plant and Equipment [Abstract]
Property, plant and equipment	Property, plant and equipment, net, consists of the following (in thousands): Useful Life (in years) June 30, December 31, Land Infinite $ 14,635 $ 18,145 Construction in progress N/A 52,811 55,622 Buildings and improvements 4 to 40 10,116 16,235 Transportation equipment 5 to 15 22,527 22,697 Processing and treating plants 8 to 40 123,210 123,138 Pipelines, compressors and right-of-way 3 to 40 1,004,992 974,301 Storage 3 to 40 46,398 146,105 Equipment 3 to 31 61,353 80,220 Total property, plant and equipment 1,336,042 1,436,463 Accumulated depreciation (343,383 ) (340,878 ) Property, plant and equipment, net $ 992,659 $ 1,095,585

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	6 Months Ended
	Jun. 30, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Goodwill	Goodwill consists of the following (in thousands): June 30, 2018 December 31, 2017 Liquid Pipelines and Services $ 35,708 $ 35,708 Terminalling Services 11,043 88,466 Offshore Pipelines and Services 4,972 4,692 Total $ 51,723 $ 128,866
Schedule of Finite-Lived Intangible Assets	Intangible assets, net, consist of the following (in thousands): June 30, 2018 Gross carrying amount Accumulated amortization Net carrying amount Customer relationships $ 64,745 $ (15,548 ) $ 49,197 Customer contracts 94,692 (50,664 ) 44,028 Dedicated acreage 42,547 (6,904 ) 35,643 Collaborative arrangements 11,884 (1,839 ) 10,045 Noncompete agreements 1,064 (1,064 ) — Other 198 (28 ) 170 Total $ 215,130 $ (76,047 ) $ 139,083 December 31, 2017 Gross carrying amount Accumulated amortization Net carrying amount Customer relationships $ 110,483 $ (29,965 ) $ 80,518 Customer contracts 94,692 (48,173 ) 46,519 Dedicated acreage 42,547 (6,216 ) 36,331 Collaborative arrangements 11,884 (1,415 ) 10,469 Noncompete agreements 1,064 (1,064 ) — Other 198 (25 ) 173 Total $ 260,868 $ (86,858 ) $ 174,010

Investment in Unconsolidated 40

Investment in Unconsolidated Affiliates (Tables)	6 Months Ended
	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Investments in and Advances to Affiliates	The following table presents the activity in our equity method investments in unconsolidated affiliates (in thousands): Delta House (1) Emerald Transactions FPS (2,4) OGL (2,4) Destin (4) Tri-States (3) Okeanos (4) Wilprise (3) Cayenne JV (3) Total Ownership % - 12/31/2017 35.7% 35.7% 66.7% 16.7% 66.7% 25.3% 50.0% Ownership % - 6/30/2018 35.7% 35.7% 66.7% 16.7% 66.7% 25.3% 50.0% Balances at December 31, 2017 $ 90,412 $ 46,932 $ 124,245 $ 53,057 $ 22,445 $ 4,689 $ 6,654 $ 348,434 Earnings in unconsolidated affiliates 5,267 3,916 4,449 1,880 4,781 510 2,316 23,119 Contributions 826 — — — — — 3,705 4,531 Distributions (6,246 ) (7,972 ) (17,872 ) (3,316 ) (8,010 ) (538 ) (600 ) (44,554 ) Balances at June 30, 2018 $ 90,259 $ 42,876 $ 110,822 $ 51,621 $ 19,216 $ 4,661 $ 12,075 $ 331,530 ___________________________________________________ (1) Represents direct and indirect ownership interests in Class A units and common units. (2) FPS denotes Floating Production System LLC whereas OGL denotes Oil & Gas Lateral LLC. (3) Included in our Liquid Pipelines and Services segment. (4) Included in our Offshore Pipelines and Services segment.
Equity Method Investments	The following tables present the summarized combined financial information for our equity investments (amounts represent 100% of investee financial information) (in thousands): Balance Sheets: June 30, 2018 December 31, 2017 Current assets $ 65,283 $ 80,405 Non-current assets 1,272,593 1,288,862 Current liabilities 117,591 130,904 Non-current liabilities 447,654 436,584 Three months ended June 30, Six months ended June 30, Statements of Operations: 2018 2017 (1) 2018 2017 (1) Revenue $ 51,790 $ 105,373 $ 108,689 $ 203,366 Operating expenses 8,213 25,781 14,507 51,977 Net income 27,303 76,414 60,149 145,532 _________________________ (1) In August 2017, we acquired 100% of the interest in POGS, the outstanding interests in one of our equity investments. We have consolidated this entity from the acquisition date. See Note 4 - Acquisitions and Dispositions for further discussion.

Accrued Expenses and Other Cu41

Accrued Expenses and Other Current Liabilities (Tables)	6 Months Ended
	Jun. 30, 2018
Other Liabilities Disclosure [Abstract]
Schedule of Accrued Liabilities	Accrued expenses and other current liabilities consists of the following (in thousands): June 30, 2018 December 31, 2017 Capital expenditures $ 8,137 $ 10,721 Accrued interest 6,485 3,190 Convertible preferred unit distributions 8,474 — Current portion of asset retirement obligation 6,416 6,416 Additional Blackwater acquisition consideration 5,000 5,000 Taxes payable 3,676 5,263 Due to related parties 5,225 6,609 Royalties, gas imbalance and leases payables 6,423 7,905 Professional fees 4,566 1,848 Other 12,993 21,902 Total accrued expenses and other current liabilities $ 67,395 $ 68,854

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2018
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	The following table presents activity in our asset retirement obligations for the six months ended June 30, 2018 (in thousands): Non-current balance $ 66,194 Current balance 6,416 Balances at December 31, 2017 72,610 Additions 260 Expenditures (7 ) Accretion expense 911 Balances at June 30, 2018 73,774 Less: current portion 6,416 Noncurrent asset retirement obligation $ 67,358

Debt Obligations (Tables)

Debt Obligations (Tables)	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Schedule of financial covenants	The Credit Agreement includes the following financial covenants, as amended by the Amendment and defined in the Credit Agreement, which financial covenants will be tested on a quarterly basis, for the fiscal quarter then ending: Consolidated Interest Coverage Ratio Consolidated Total Leverage Ratio Consolidated Secured Leverage Ratio June 30, 2018 2.50:1.00 6.15:1.00 4.00:1.00 September 30, 2018 2.00:1.00 6.25:1.00 3.75:1.00 December 31, 2018 1.75:1.00 5.50:1.00 3.50:1.00 March 31, 2019 1.75:1.00 5.00:1.00 (1) 3.50:1.00 June 30, 2019 and thereafter 2.00:1.00 5.00:1.00 (1) 3.50:1.00 ___________________________ (1) 5.50 :1.00 during a Specified Acquisition Period As of June 30, 2018 , after giving effect to the amendments to the ratios, we were in compliance with our Credit Agreement financial covenants, including those shown below: Ratio Actual Minimum Consolidated Interest Coverage Ratio 3.11 Maximum Allowable Consolidated Total Leverage Ratio 5.42 Maximum Allowable Consolidated Secured Leverage Ratio 3.50
Outstanding borrowings under the credit facility	Our outstanding debt consists of the following (in thousands): June 30, 2018 December 31, 2017 Revolving credit facility $ 776,300 $ 697,900 8.50% Senior unsecured notes, due 2021 425,000 425,000 3.77% Senior secured notes, due 2031 (non-recourse) 57,679 58,324 3.97% Senior secured notes, due 2032 (non-recourse) 31,148 32,025 Other debt 579 4,989 Total debt obligations 1,290,706 1,218,238 Unamortized debt issuance costs (9,020 ) (9,231 ) Total debt 1,281,686 1,209,007 Less: Current portion, including unamortized debt issuance costs (3,624 ) (7,551 ) Long term debt $ 1,278,062 $ 1,201,456
Schedule of redemption percentages	On and after December 15, 2018, we may redeem all or a part of the 8.50% Senior Notes, at the redemption prices set forth below, plus accrued and unpaid interest, if redeemed during the twelve -month period beginning on December 15 of the years indicated below: Year Percentage 2018 104.250% 2019 102.125% 2020 and thereafter 100.000%

Convertible Preferred Units (Ta

Convertible Preferred Units (Tables)	6 Months Ended
	Jun. 30, 2018
Partners' Capital [Abstract]
Schedule of Preferred Units	Our convertible preferred units consist of the following (in thousands): Series A Series C Total Units $ Units $ $ December 31, 2017 10,719 $ 191,798 8,965 $ 125,382 $ 317,180 Paid in kind unit distributions 291 — 277 — — June 30, 2018 11,010 $ 191,798 9,242 $ 125,382 $ 317,180

Partners Capital (Tables)

Partners Capital (Tables)	6 Months Ended
	Jun. 30, 2018
Equity [Abstract]
Schedule of Units Outstanding and Distributions	The following table presents unit activity (in thousands): General Limited Partner Interest Balances at December 31, 2017 965 52,711 LTIP vesting — 261 Balances at June 30, 2018 965 52,972 The following table details cash distributions paid or accrued as of, and for, the three and six months ended June 30, 2018 (in thousands): Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 Series A Units Cash Paid $ 4,542 $ 2,117 $ 4,542 $ 4,644 Accrued (1) 4,542 4,069 4,542 4,069 Paid-in-kind units — 2,181 3,767 4,914 Series C Units Cash Paid 3,812 3,627 3,812 7,254 Accrued (1) 3,812 3,627 3,812 3,627 Paid-in-kind units — — 4,309 — Series D Units Cash Paid — 963 — 1,925 Accrued — 963 — 963 Limited Partners’ Units (2) Cash Paid 21,853 21,390 43,598 46,303 General Partners’ Units (3) Cash Paid 287 201 577 368 Summary Cash Paid $ 30,494 $ 28,298 $ 52,529 $ 60,494 Accrued (1) 8,354 8,659 8,354 8,659 Paid-in-kind units — 2,181 8,076 4,914 __________________________ (1) Can be paid in either Cash, PIK or a combination of both. (2) Limited Partner distributions do not include $5.5 million and $21.4 million of distributions declared in the third quarter which relate to the second quarter of 2018 and 2017, respectively. (3) General Partner distributions do not include $0.1 million and $0.3 million of distributions declared in the third quarter which relate to the second quarter of 2018 and 2017, respectively.
Schedule of Distributions Declared and Paid	The following table reflects distributions declared and paid through June 30, 2018 (in thousands, except per unit data): Date Declared Distribution Payment Date General Partner Limited Partner Total Cash Distributions Cash Distributions Per Common Unit April 26, 2018 May 15, 2018 $ 287 $ 21,853 $ 22,140 $ 0.4125 January 26, 2018 February 14, 2018 $ 290 $ 21,745 $ 22,035 $ 0.4125

Net Loss per Limited Partner 46

Net Loss per Limited Partner Unit (Tables)	6 Months Ended
	Jun. 30, 2018
Earnings Per Share [Abstract]
Schedule of Calculation for Net Loss Per Limited Partner Unit	The calculation of basic and diluted limited partners' net loss per common unit is summarized below (in thousands, except per unit amounts): Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 Loss from continuing operations $ (17,274 ) $ (25,901 ) $ (31,116 ) $ (54,072 ) Less: Net income attributable to noncontrolling interests 13 1,462 57 2,765 Loss attributable to the Partnership (17,287 ) (27,363 ) (31,173 ) (56,837 ) Less: Distributions on Series A Units 4,542 4,069 9,084 8,367 Distributions on Series C Units 3,812 3,627 7,624 7,254 Distributions on Series D Units — 963 — 1,925 General Partner's distribution 72 277 361 476 General Partner's share in undistributed loss (403 ) (784 ) (986 ) (1,541 ) Loss attributable to Limited Partners (25,310 ) (35,515 ) (47,256 ) (73,318 ) Loss from discontinued operations, net of tax — (1,801 ) — (2,511 ) Net loss attributable to Limited Partners $ (25,310 ) $ (37,316 ) $ (47,256 ) $ (75,829 ) Weighted average number of common units outstanding - Basic and Diluted 52,969 51,870 52,869 51,870 Limited Partners' net loss per common unit - Basic and Diluted Loss from continuing operations $ (0.48 ) $ (0.69 ) $ (0.89 ) $ (1.41 ) Loss from discontinued operations — (0.03 ) — (0.05 ) Net loss (1) $ (0.48 ) $ (0.72 ) $ (0.89 ) $ (1.46 ) _____________________________________ (1) Potential common unit equivalents are antidilutive for all periods presented and, as a result, 23.9 million and 24.0 million potential common unit equivalents for the three and six months ended June 30, 2018 and 2017, respectively and have been excluded from the determination of diluted limited partners' net loss per common unit.

Incentive Compensation (Tables)

Incentive Compensation (Tables)	6 Months Ended
	Jun. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Components of Equity-Based Compensation Expense	The following table presents the components of equity-based compensation expense for the three and six months ended June 30, 2018 and 2017 (in thousands): Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 Grant Type: RSU $ 835 $ 1,177 $ 1,534 $ 5,195 PSU 330 — 630 — Options 15 19 30 38 Total $ 1,180 $ 1,196 $ 2,194 $ 5,233

Supplemental Cash Flow Inform48

Supplemental Cash Flow Information (Tables)	6 Months Ended
	Jun. 30, 2018
Supplemental Cash Flow Elements [Abstract]
Schedule of Supplemental Cash Flow Information	Supplemental cash flows and non-cash transactions consist of the following (in thousands): Six months ended June 30, 2018 2017 Supplemental cash flow information Interest payments, net of capitalized interest $ 36,778 $ 27,324 Supplemental non-cash information Investing Increase (decrease) in accrued property, plant and equipment purchases (2,584 ) (3,131 ) Accrued contributions to unconsolidated affiliates (1,585 ) — Financing Contributions from an affiliate holding limited partner interests — 4,000 Accrued distributions on convertible preferred units 8,354 8,659 Paid-in-kind distributions on convertible preferred units 8,076 4,914

Reportable Segments (Tables)

Reportable Segments (Tables)	6 Months Ended
	Jun. 30, 2018
Segment Reporting [Abstract]
Segment information	The following tables set forth our segment information for the three and six months ended June 30, 2018 and 2017 (in thousands): Three months ended June 30, 2018 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 49,509 $ 120,617 $ 15,567 $ 18,519 $ 16,360 $ 220,572 Gain (loss) on commodity derivatives, net (294 ) (61 ) — — — (355 ) Total revenue 49,215 120,556 15,567 18,519 16,360 220,217 Operating expenses: Cost of Sales 34,948 115,193 5,839 2,150 3,378 161,508 Direct operating expenses — — — — 4,131 21,742 Corporate expenses 23,372 Depreciation, amortization and accretion expense 21,236 Total operating expenses 227,858 Operating income (loss) (7,641 ) Other income (expense), net Interest expense, net of capitalized interest (19,691 ) Other income (expense), net 169 Earnings in unconsolidated affiliates — 2,485 — 7,961 — 10,446 Income (loss) from continuing operations before income taxes (16,717 ) Income tax expense (557 ) Loss from continuing operations (17,274 ) Less: Net income attributable to non-controlling interests 13 Net loss attributable to the Partnership $ (17,287 ) Segment gross margin $ 14,539 $ 7,744 $ 9,653 $ 24,330 $ 8,851 Three months ended June 30, 2017 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 39,307 $ 83,157 $ 11,397 $ 12,139 $ 15,831 $ 161,831 Gain (loss) on commodity derivatives, net (98 ) 297 — — — 199 Total revenue 39,209 83,454 11,397 12,139 15,831 162,030 Operating expenses: Cost of Sales 26,582 78,101 5,678 2,586 2,073 115,020 Direct operating expenses — — — — 2,998 18,709 Corporate expenses 27,374 Depreciation, amortization and accretion expense 26,483 Gain on sale of assets, net 18 Total operating expenses 187,604 Operating income (loss) (25,574 ) Other income (expenses), net Interest expense, net of capitalized interest (17,122 ) Earnings in unconsolidated affiliates — 1,482 — 16,070 — 17,552 Income (loss) from continuing operations before income taxes (25,144 ) Income tax expense (757 ) Loss from continuing operations (25,901 ) Loss from discontinued operations (1,801 ) Net loss (27,702 ) Less: Net income attributable to non-controlling interests 1,462 Net loss attributable to the Partnership $ (29,164 ) Segment gross margin $ 12,651 $ 6,765 $ 5,631 $ 25,623 $ 10,760 Six months ended June 30, 2018 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 85,185 $ 240,388 $ 31,629 $ 35,380 $ 33,758 — $ 426,340 Gain (loss) on commodity derivatives, net (292 ) (4 ) — — — — (296 ) Total revenue 84,893 240,384 31,629 35,380 33,758 426,044 Operating expenses: Cost of Sales 58,003 229,998 11,126 4,146 8,401 — 311,674 Direct operating expenses — — — — 8,453 — 45,189 Corporate expenses — 46,064 Depreciation, amortization and accretion expense 43,234 Gain on sale of assets, net (95 ) Total operating expenses 446,066 Operating income (loss) (20,022 ) Other income (expense), net Interest expense, net of capitalized interest (33,567 ) Other income (expense), net 191 Earnings in unconsolidated affiliates — 4,706 — 18,413 — — 23,119 Loss from continuing operations before income taxes (30,279 ) Income tax expense (837 ) Loss from continuing operations (31,116 ) Net loss (31,116 ) Less: Net income attributable to non-controlling interests — 57 Net loss attributable to the Partnership $ (31,173 ) — Segment gross margin $ 27,193 $ 15,014 $ 20,340 $ 49,647 $ 16,904 Six months ended June 30, 2017 Gas Gathering and Processing Services Liquid Pipelines and Services Natural Gas Transportation Services Offshore Pipelines and Services Terminalling Services Total Revenue $ 73,714 $ 166,568 $ 23,835 $ 26,970 $ 34,457 $ 325,544 Gain (loss) on commodity derivatives, net (105 ) 669 — — — 564 Total revenue 73,609 167,237 23,835 26,970 34,457 326,108 Operating expenses: Cost of Sales 49,769 156,386 11,938 5,929 6,466 230,488 Direct operating expenses — — — — 6,071 36,114 Corporate expenses 57,487 Depreciation, amortization and accretion expense 52,053 Gain on sale of assets, net (3 ) Total operating expenses 376,139 Operating income (loss) (50,031 ) Other income (expenses), net Interest expense, net of capitalized interest (35,078 ) Other income (expense), net (37 ) Earnings in unconsolidated affiliates — 2,569 — 30,385 — 32,954 Loss from continuing operations before income taxes (52,192 ) Income tax expense (1,880 ) Loss from continuing operations (54,072 ) Loss from discontinued operations (2,511 ) Net loss (56,583 ) Less: Net income attributable to non-controlling interests 2,765 Net loss attributable to the Partnership $ (59,348 ) Segment gross margin $ 23,902 $ 13,401 $ 11,750 $ 51,426 $ 21,920 A reconciliation of total assets by segment to the amounts included in the Condensed Consolidated Balance Sheets follows (in thousands): June 30, December 31, 2018 2017 Segment assets: Gas Gathering and Processing Services $ 388,147 $ 404,872 Liquid Pipelines and Services 374,668 359,646 Offshore Pipelines and Services 521,710 553,213 Natural Gas Transportation Services 266,972 268,991 Terminalling Services 289,226 293,085 Other (1) 100,604 43,659 Total assets $ 1,941,327 $ 1,923,466 Investment in equity method investees: Liquid Pipelines and Services $ 68,357 $ 64,399 Offshore Pipelines and Services 263,173 284,035 Total Investment in equity method investees $ 331,530 $ 348,434 ________________________ (1) Other assets consists primarily of corporate assets not allocable to segments, such as leasehold improvements and other current assets. The following table sets forth capital expenditures for the three and six months ended June 30, 2018 and 2017 by segment (in thousands): Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 Capital expenditures Gas Gathering and Processing Services $ 6,657 $ 4,143 $ 13,311 $ 8,526 Liquid Pipelines and Services 4,767 1,005 11,180 1,376 Offshore Pipelines and Services 14,004 1,611 20,354 1,134 Natural Gas Transportation Services 1,154 14,138 2,492 24,366 Terminalling Services 2,416 1,031 6,122 2,841 Corporate 1,592 1,015 3,074 3,645 Total capital expenditures (1) $ 30,590 $ 22,943 $ 56,533 $ 41,888 _____________________________________ (1) Capital expenditures exclude expenditures made for the Propane Business of approximately $1.3 million and $ 2.2 million for the three and six months ended June 30, 2017, respectively, as the business was sold in 2017

Organization and Basis of Pre50

Organization and Basis of Presentation (Details)	6 Months Ended
	Jun. 30, 2018segments
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General partners' capital account, percentage	77.00%
Limited partners' capital account, percentage	23.00%
Number of reportable segments	5

New Accounting Pronouncements -

New Accounting Pronouncements - Effect of Adoption of New Accounting Pronouncements (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Net loss	$ (17,274)	$ (27,702)	$ (31,116)	$ (56,583)
Adjustments to reconcile net loss to net cash provided by operating activities including discontinued operations				78,200
Restricted cash, short-term				0
Changes in operating assets and liabilities, net of effects of assets acquired and liabilities assumed (excluding restricted cash)				6,741
Net cash provided by operating activities			8,960	28,358
Restricted cash				0
Other investing activities (excluding restricted cash)				(70,328)
Net cash used in investing activities			(36,321)	(70,328)
Other financing activities				(257,354)
Net cash provided by (used in) financing activities			40,182	(257,354)
Net increase (decrease) in cash, cash equivalents, and restricted cash			12,821	(299,324)
Beginning of period			34,179	329,230
End of period	47,000	29,906	47,000	29,906
Goodwill	51,723		51,723		$ 128,866
As Previously Reported
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Net loss				(56,583)
Adjustments to reconcile net loss to net cash provided by operating activities including discontinued operations				78,200
Restricted cash, short-term				(3,135)
Changes in operating assets and liabilities, net of effects of assets acquired and liabilities assumed (excluding restricted cash)				6,794
Net cash provided by operating activities				25,276
Restricted cash				302,643
Other investing activities (excluding restricted cash)				(70,328)
Net cash used in investing activities				232,315
Other financing activities				(257,354)
Net cash provided by (used in) financing activities				(257,354)
Net increase (decrease) in cash, cash equivalents, and restricted cash				237
Beginning of period				5,666
End of period		5,903		5,903
ASU 2016-15 and ASU 2016-18 | Effect of Adoption
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Net loss				0
Adjustments to reconcile net loss to net cash provided by operating activities including discontinued operations				0
Restricted cash, short-term				3,135
Changes in operating assets and liabilities, net of effects of assets acquired and liabilities assumed (excluding restricted cash)				(53)
Net cash provided by operating activities				3,082
Restricted cash				(302,643)
Other investing activities (excluding restricted cash)				0
Net cash used in investing activities				(302,643)
Other financing activities				0
Net cash provided by (used in) financing activities				0
Net increase (decrease) in cash, cash equivalents, and restricted cash				(299,561)
Beginning of period				323,564
End of period		$ 24,003		$ 24,003
Liquid Pipelines and Services
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Goodwill	35,708		35,708		35,708
Terminalling Services
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Goodwill	$ 11,043		$ 11,043		88,466
Cushing and Silver Dollar Reporting Units [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Goodwill					46,800
Silver Dollar Reporting Unit [Member] | Liquid Pipelines and Services
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Goodwill					$ 35,700
Cushing Reporting Unit [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Reporting Unit, Percentage of Fair Value in Excess of Carrying Amount					7.00%
Cushing Reporting Unit [Member] | Terminalling Services
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Goodwill					$ 11,100

Revenue Recognition - Impact of

Revenue Recognition - Impact of Adopting New Accounting Pronouncement on income Statement (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Commodity sales	$ 164,737	$ 124,476	$ 323,599	$ 247,997
Services	55,835	37,355	102,741	77,547
Cost of Sales	161,508	115,020	311,674	230,488
Direct operating expenses	21,742	18,709	45,189	36,114
Operating loss	(7,641)	(25,574)	(20,022)	(50,031)
Net loss attributable to the Partnership	(17,287)	(29,164)	(31,173)	(59,348)
General Partner’s interest in net loss	(225)	(375)	(405)	(795)
Limited Partners’ interest in net loss	(17,062)	$ (28,789)	(30,768)	$ (58,553)
Adjustments | ASU 2014-09
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Commodity sales	12,535		17,777
Services	(12,304)		(14,985)
Cost of Sales	5,409		8,574
Direct operating expenses	(4,550)		(5,006)
Operating loss	(628)		(776)
Net loss attributable to the Partnership	(628)		(776)
General Partner’s interest in net loss	(8)		(10)
Limited Partners’ interest in net loss	(620)		(766)
Amounts without Adoption of Topic 606 | ASU 2014-09
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Commodity sales	177,272		341,376
Services	43,531		87,756
Cost of Sales	166,917		320,248
Direct operating expenses	17,192		40,183
Operating loss	(8,269)		(20,798)
Net loss attributable to the Partnership	(17,915)		(31,949)
General Partner’s interest in net loss	(233)		(415)
Limited Partners’ interest in net loss	$ (17,682)		$ (31,534)

Revenue Recognition - Impact 53

Revenue Recognition - Impact of Adopting New Accounting Pronouncement on Balance Sheet (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Accounts receivable, net	$ 88,352	$ 98,132
Other current assets	30,570	23,420
Other assets, net	27,984	17,874
Other long-term liabilities	15,426	$ 2,080
Liabilities held for sale	2,237
Adjustments | ASU 2014-09
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Accounts receivable, net	(76,684)
Unbilled revenue	76,684
Other current assets	(252)
Other assets, net	(6,984)
Other long-term liabilities	(13,865)
Liabilities held for sale	(690)
Amounts without Adoption of Topic 606 | ASU 2014-09
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Accounts receivable, net	11,668
Unbilled revenue	76,684
Other current assets	30,318
Other assets, net	21,000
Other long-term liabilities	1,561
Liabilities held for sale	$ 1,547

Revenue Recognition - Disaggreg

Revenue Recognition - Disaggregated Revenues (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2018
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 220,572	$ 426,340
Gathering and processing
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	13,871	20,987
Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	23,855	45,621
Terminalling and storage
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	12,150	23,983
Other services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,959	12,150
Gas Gathering and Processing Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	49,509	85,185
Gas Gathering and Processing Services | Gathering and processing
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	12,463	18,713
Gas Gathering and Processing Services | Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	143	248
Gas Gathering and Processing Services | Terminalling and storage
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Gas Gathering and Processing Services | Other services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	534	968
Liquid Pipelines and Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	120,617	240,388
Liquid Pipelines and Services | Gathering and processing
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Liquid Pipelines and Services | Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3,626	7,214
Liquid Pipelines and Services | Terminalling and storage
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Liquid Pipelines and Services | Other services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	475	877
Natural Gas Transportation Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	15,567	31,629
Natural Gas Transportation Services | Gathering and processing
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Natural Gas Transportation Services | Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	9,857	19,269
Natural Gas Transportation Services | Terminalling and storage
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Natural Gas Transportation Services | Other services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	235	244
Offshore Pipelines and Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	18,519	35,380
Offshore Pipelines and Services | Gathering and processing
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,408	2,274
Offshore Pipelines and Services | Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	10,229	18,890
Offshore Pipelines and Services | Terminalling and storage
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Offshore Pipelines and Services | Other services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,175	8,960
Terminalling Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	16,360	33,758
Terminalling Services | Gathering and processing
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Terminalling Services | Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Terminalling Services | Terminalling and storage
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	12,150	23,983
Terminalling Services | Other services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	540	1,101
Natural gas | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11,581	22,561
Natural gas | Gas Gathering and Processing Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3,521	5,427
Natural gas | Liquid Pipelines and Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Natural gas | Natural Gas Transportation Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,473	12,110
Natural gas | Offshore Pipelines and Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,587	5,024
Natural gas | Terminalling Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
NGLs | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	18,092	39,280
NGLs | Gas Gathering and Processing Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	18,059	39,209
NGLs | Liquid Pipelines and Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
NGLs | Natural Gas Transportation Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
NGLs | Offshore Pipelines and Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	33	71
NGLs | Terminalling Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Condensate | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	14,217	19,899
Condensate | Gas Gathering and Processing Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	14,154	19,802
Condensate | Liquid Pipelines and Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Condensate | Natural Gas Transportation Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Condensate | Offshore Pipelines and Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	63	97
Condensate | Terminalling Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Crude oil | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	116,516	232,297
Crude oil | Gas Gathering and Processing Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Crude oil | Liquid Pipelines and Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	116,516	232,297
Crude oil | Natural Gas Transportation Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Crude oil | Offshore Pipelines and Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Crude oil | Terminalling Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Other sales | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,331	9,562
Other sales | Gas Gathering and Processing Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	635	818
Other sales | Liquid Pipelines and Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Other sales | Natural Gas Transportation Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2	6
Other sales | Offshore Pipelines and Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	24	64
Other sales | Terminalling Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 3,670	$ 8,674

Revenue Recognition - Reconcili

Revenue Recognition - Reconciliation of Revenues From Contracts With Customers (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 220,572		$ 426,340
Loss on commodity derivatives, net	(355)	$ 199	(296)	$ 564
Total revenue	220,217	162,030	426,044	326,108
Gas Gathering and Processing Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	49,509		85,185
Loss on commodity derivatives, net	(294)		(292)
Total revenue	49,215		84,893
Liquid Pipelines and Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	120,617		240,388
Loss on commodity derivatives, net	(61)		(4)
Total revenue	120,556		240,384
Natural Gas Transportation Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	15,567		31,629
Loss on commodity derivatives, net	0		0
Total revenue	15,567		31,629
Offshore Pipelines and Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	18,519		35,380
Loss on commodity derivatives, net	0		0
Total revenue	18,519		35,380
Terminalling Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	16,360		33,758
Loss on commodity derivatives, net	0		0
Total revenue	16,360		33,758
Operating Segments | Gas Gathering and Processing Services
Disaggregation of Revenue [Line Items]
Loss on commodity derivatives, net		(98)	(292)	(105)
Total revenue	49,215	39,209	84,893	73,609
Operating Segments | Liquid Pipelines and Services
Disaggregation of Revenue [Line Items]
Loss on commodity derivatives, net	(61)	297	(4)	669
Total revenue	120,556	83,454	240,384	167,237
Operating Segments | Natural Gas Transportation Services
Disaggregation of Revenue [Line Items]
Loss on commodity derivatives, net	0	0	0	0
Total revenue	15,567	11,397	31,629	23,835
Operating Segments | Offshore Pipelines and Services
Disaggregation of Revenue [Line Items]
Loss on commodity derivatives, net	0	0	0	0
Total revenue	18,519	12,139	35,380	26,970
Operating Segments | Terminalling Services
Disaggregation of Revenue [Line Items]
Loss on commodity derivatives, net	0	0	0	0
Total revenue	$ 16,360	$ 15,831	$ 33,758	$ 34,457

Revenue Recognition - Change in

Revenue Recognition - Change in Contract Balances (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2018
Contract Assets
Balance at June 30, 2018	$ 7,236
Current		$ 252
Noncurrent		6,984
Accounts receivable, net	7,236	7,236
Contract Liabilities
Balance at June 30, 2018	15,890
Current	1,194
Noncurrent	14,696
Contract with Customer, Liability	15,890	15,890
Held-for-sale
Contract Assets
Balance at June 30, 2018	0
Accounts receivable, net	0	0
Contract Liabilities
Balance at June 30, 2018	690
Contract with Customer, Liability	690	690
Continuing Operations, Including Assets Held for Sale
Contract Assets
Balance at December 31, 2017	0
Topic 606 implementation	2,555
Additions	4,681
Balance at June 30, 2018	7,236
Accounts receivable, net	0	7,236
Contract Liabilities
Balance at December 31, 2017	2,136
Topic 606 implementation	13,246
Amounts recognized as revenue	(1,463)
Additions	2,661
Balance at June 30, 2018	15,890
Contract with Customer, Liability	$ 2,136	$ 15,890

Revenue Recognition - Remaining

Revenue Recognition - Remaining Performance Obligation (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	$ 25,313
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	$ 47,445
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	$ 39,727
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	$ 34,438
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	$ 32,986
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	$ 212,847
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	$ 392,756
Gathering and processing | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	6,165
Gathering and processing | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	12,738
Gathering and processing | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	12,738
Gathering and processing | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	12,715
Gathering and processing | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	12,461
Gathering and processing | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	19,116
Gathering and processing | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	75,933
Transportation | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	11,232
Transportation | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	20,163
Transportation | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	19,225
Transportation | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	19,029
Transportation | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	18,943
Transportation | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	193,731
Transportation | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	282,323
Terminalling and storage | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	7,070
Terminalling and storage | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	12,896
Terminalling and storage | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	6,204
Terminalling and storage | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	2,694
Terminalling and storage | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	1,582
Terminalling and storage | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	0
Terminalling and storage | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	30,446
Other services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	846
Other services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	1,648
Other services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	1,560
Other services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	0
Other services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	0
Other services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	0
Other services | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	$ 4,054

Acquisitions and Dispositions58

Acquisitions and Dispositions (Narrative) (Details) $ in Thousands	Nov. 03, 2017USD ($)	Oct. 27, 2017USD ($)	Sep. 29, 2017USD ($)	Sep. 01, 2017USD ($)location	Aug. 08, 2017USD ($)	Jun. 02, 2017USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Jun. 16, 2018USD ($)	Feb. 16, 2018USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Payments to acquire equity method investments							$ 2,946	$ 0
Refined Products Terminals And Storage Segment
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Sale price per definitive agreement										$ 138,500
Marine Liquids Terminals
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Sale price per definitive agreement									$ 210,000
Propane Marketing Services | Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of business and assets, net of cash on hand				$ 170,000
Gain on discontinued operations				47,400
Transaction costs				$ 2,500
Propane Marketing Services | Propane Business | Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Number of service locations divested | location				40
Destin | American Midstream Emerald, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity interests acquired (percent)		17.00%
Total consideration upon acquisition		$ 30,000
Delta House
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity interests acquired (percent)			15.50%
Payments to acquire equity method investments			$ 125,400
Viosca Knoll
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity interests acquired (percent)						100.00%
Cash payment made to acquire business						$ 32,000
Panther
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity interests acquired (percent)					100.00%
Total consideration upon acquisition					$ 60,900
Trans-Union Pipeline, L.P. (“Trans-Union”)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity interests acquired (percent)	100.00%
Cash payment made to acquire business	$ 16,900
Total consideration upon acquisition	49,400
Non-recourse debt assumed	$ 32,500

Acquisitions and Dispositions59

Acquisitions and Dispositions (Condensed Balance Sheets) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and cash equivalents	$ 364	$ 0	$ 364	$ 0
Held-for-sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and cash equivalents	364		364
Accounts receivable, net	4,355		4,355
Inventory	537		537
Other current assets	357		357
Property, plant and equipment, net	116,993		116,993
Goodwill	77,425		77,425
Intangible assets	29,403		29,403
Other non-current assets	695		695
Total assets held for sale	230,129		230,129
Accounts payable	196		196
Accrued gas purchases	72		72
Accrued expenses and other current liabilities	1,397		1,397
Other long-term liabilities	572		572
Total liabilities of discontinued operations	2,237		2,237
Refined Products Business
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net income from continuing operations before income taxes	4,300	1,600	6,700	3,400
Refined Products Business | Refined Products Terminals And Storage Segment | Held-for-sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and cash equivalents	0		0
Accounts receivable, net	1,834		1,834
Inventory	506		506
Other current assets	213		213
Property, plant and equipment, net	32,332		32,332
Goodwill	61,163		61,163
Intangible assets	29,403		29,403
Other non-current assets	692		692
Total assets held for sale	126,143		126,143
Accounts payable	44		44
Accrued gas purchases	72		72
Accrued expenses and other current liabilities	991		991
Other long-term liabilities	572		572
Total liabilities of discontinued operations	1,679		1,679
Marine Products Business
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net income from continuing operations before income taxes	3,500	$ 2,500	5,100	$ 5,200
Marine Products Business | Marine Liquids Terminals | Held-for-sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and cash equivalents	364		364
Accounts receivable, net	2,521		2,521
Inventory	31		31
Other current assets	144		144
Property, plant and equipment, net	84,661		84,661
Goodwill	16,262		16,262
Intangible assets	0		0
Other non-current assets	3		3
Total assets held for sale	103,986		103,986
Accounts payable	152		152
Accrued gas purchases	0		0
Accrued expenses and other current liabilities	406		406
Other long-term liabilities	0		0
Total liabilities of discontinued operations	$ 558		$ 558

Acquisitions and Dispositions60

Acquisitions and Dispositions (Condensed Statements of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Loss from discontinued operations	$ 0	$ (1,801)	$ 0	$ (2,511)
Propane Business | Propane Marketing Services | Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total revenue		31,603		67,157
Total operating expenses		33,402		69,707
Operating loss		(1,799)		(2,550)
Other income		42		83
Income tax expense		(44)		(44)
Loss from discontinued operations		(1,801)		(2,511)
Depreciation and amortization		3,687		7,468
Capital expenditures		1,302		2,421
Unrealized loss on derivative contracts, net		$ (60)		$ (961)

Inventory (Details)

Inventory (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Inventory Disclosure [Abstract]
Crude oil	$ 2,184	$ 1,553
NGLs	357	347
Refined products	0	934
Materials, supplies and equipment	120	132
Total inventory	$ 2,661	$ 2,966

Other Current Assets (Details)

Other Current Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Prepaid expenses	$ 7,196	$ 8,944
Insurance receivables	881	1,741
Due from related parties	6,773	4,362
Other receivables	8,801	5,187
Risk management assets	6,919	3,186
Total other current assets	$ 30,570	$ 23,420

Risk Management Activities (Com

Risk Management Activities (Commodity-related Derivatives) (Details) - gal	6 Months Ended	12 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Propane | Propane, Fixed Price Commodity Swap Contract
Derivative [Line Items]
Derivative, volume	2,188,200	0

Risk Management Activities (Int

Risk Management Activities (Interest Rate Swaps) (Details) - USD ($)	Jun. 30, 2018	Dec. 31, 2017
Interest Rate Swap
Derivative [Line Items]
Notional Amount	$ 550,000,000	$ 550,000,000

Risk Management Activities (Nar

Risk Management Activities (Narrative) (Details) - Weather Derivative - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Derivative [Line Items]
Potential proceeds from derivative contract	$ 20,000,000	$ 30,000,000
Premium payments	1,000,000	$ 1,000,000	$ 1,100,000	$ 1,100,000
Term of contract			1 year
Debt instrument, unamortized premium	$ 900,000		$ 900,000		$ 500,000

Risk Management Activities (Fai

Risk Management Activities (Fair Value of Commodity Derivatives) (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Asset Derivatives
Total	$ 18,524	$ 11,993
Liability Derivatives
Total	(240)	0
Accrued Expenses and Other Liabilities | Commodity derivatives
Asset Derivatives
Total	0	0
Liability Derivatives
Total	(240)	0
Other current assets | Interest rate swaps
Asset Derivatives
Total	5,970	2,677
Liability Derivatives
Total	0	0
Other current assets | Weather derivatives
Asset Derivatives
Total	949	509
Liability Derivatives
Total	0	0
Other assets net | Interest rate swaps
Asset Derivatives
Total	11,605	8,807
Liability Derivatives
Total	$ 0	$ 0

Risk Management Activities (Rea

Risk Management Activities (Realized and Unrealized Gains (Losses)) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Derivatives, Fair Value [Line Items]
Realized	$ (355)	$ 199	$ (296)	$ 564
Commodity Contract
Derivatives, Fair Value [Line Items]
Realized	839	(26)	2,029	68
Unrealized	739	(1,686)	5,851	(2,059)
Commodity Contract | Gains (losses) on commodity derivatives, net
Derivatives, Fair Value [Line Items]
Realized	(174)	192	(56)	613
Unrealized	(181)	7	(240)	(49)
Commodity Contract | Interest expense
Derivatives, Fair Value [Line Items]
Realized	1,285	0	2,635	(70)
Unrealized	920	(1,693)	6,091	(2,010)
Commodity Contract | Direct operating expenses
Derivatives, Fair Value [Line Items]
Realized	(272)	(218)	(550)	(475)
Unrealized	$ 0	$ 0	$ 0	$ 0

Risk Management Activities (Fin

Risk Management Activities (Financial Instruments Not Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	$ 504,808	$ 506,118
Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	$ 499,012	$ 521,128
8.5% Senior Unsecured Notes | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt instrument, stated interest rate (percent)	8.50%	8.50%
8.5% Senior Unsecured Notes | Carrying Amount | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	$ 418,537	$ 418,421
8.5% Senior Unsecured Notes | Fair Value | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	$ 420,137	$ 437,062
3.77% Senior Secured Notes | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt instrument, stated interest rate (percent)	3.77%	3.77%
3.77% Senior Secured Notes | Carrying Amount | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	$ 55,447	$ 56,005
3.77% Senior Secured Notes | Fair Value | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	$ 50,822	$ 53,845
3.97% Trans-Union Secured Senior Notes | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt instrument, stated interest rate (percent)	3.97%	3.97%
3.97% Trans-Union Secured Senior Notes | Carrying Amount | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	$ 30,824	$ 31,692
3.97% Trans-Union Secured Senior Notes | Fair Value | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	$ 28,053	$ 30,221

Property, Plant and Equipment69

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Property, Plant and Equipment, Net [Abstract]
Total property, plant and equipment	$ 1,336,042	$ 1,436,463
Accumulated depreciation	(343,383)	(340,878)
Property, plant and equipment, net	992,659	1,095,585
Land
Property, Plant and Equipment, Net [Abstract]
Total property, plant and equipment	14,635	18,145
Construction in progress
Property, Plant and Equipment, Net [Abstract]
Total property, plant and equipment	52,811	55,622
Buildings and improvements
Property, Plant and Equipment, Net [Abstract]
Total property, plant and equipment	10,116	16,235
Transportation equipment
Property, Plant and Equipment, Net [Abstract]
Total property, plant and equipment	22,527	22,697
Processing and treating plants
Property, Plant and Equipment, Net [Abstract]
Total property, plant and equipment	123,210	123,138
Pipelines, compressors and right-of-way
Property, Plant and Equipment, Net [Abstract]
Total property, plant and equipment	1,004,992	974,301
Storage
Property, Plant and Equipment, Net [Abstract]
Total property, plant and equipment	46,398	146,105
Equipment
Property, Plant and Equipment, Net [Abstract]
Total property, plant and equipment	$ 61,353	$ 80,220
Minimum | Buildings and improvements
Property, Plant and Equipment, Net [Abstract]
Useful Life (in years)	4 years
Minimum | Transportation equipment
Property, Plant and Equipment, Net [Abstract]
Useful Life (in years)	5 years
Minimum | Processing and treating plants
Property, Plant and Equipment, Net [Abstract]
Useful Life (in years)	8 years
Minimum | Pipelines, compressors and right-of-way
Property, Plant and Equipment, Net [Abstract]
Useful Life (in years)	3 years
Minimum | Storage
Property, Plant and Equipment, Net [Abstract]
Useful Life (in years)	3 years
Minimum | Equipment
Property, Plant and Equipment, Net [Abstract]
Useful Life (in years)	3 years
Maximum | Buildings and improvements
Property, Plant and Equipment, Net [Abstract]
Useful Life (in years)	40 years
Maximum | Transportation equipment
Property, Plant and Equipment, Net [Abstract]
Useful Life (in years)	15 years
Maximum | Processing and treating plants
Property, Plant and Equipment, Net [Abstract]
Useful Life (in years)	40 years
Maximum | Pipelines, compressors and right-of-way
Property, Plant and Equipment, Net [Abstract]
Useful Life (in years)	40 years
Maximum | Storage
Property, Plant and Equipment, Net [Abstract]
Useful Life (in years)	40 years
Maximum | Equipment
Property, Plant and Equipment, Net [Abstract]
Useful Life (in years)	31 years

Property, Plant and Equipment70

Property, Plant and Equipment (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	$ 1,336,042		$ 1,336,042		$ 1,436,463
Depreciation and amortization expense	18,200	$ 18,300	36,800	$ 36,800
Interest costs capitalized	900	$ 500	1,500	$ 1,500
FERC Regulated Assets
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	$ 374,200		$ 374,200		$ 367,600

Goodwill and Intangible Asset71

Goodwill and Intangible Assets (Schedule of Goodwill) (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Goodwill [Line Items]
Goodwill	$ 51,723	$ 128,866
Liquid Pipelines and Services
Goodwill [Line Items]
Goodwill	35,708	35,708
Terminalling Services
Goodwill [Line Items]
Goodwill	11,043	88,466
Offshore Pipelines and Services
Goodwill [Line Items]
Goodwill	$ 4,972	$ 4,692

Goodwill and Intangible Asset72

Goodwill and Intangible Assets Goodwill and Intangible Assets (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 2.5	$ 7.6	$ 5.2	$ 14.2
Remainder of 2018	5.1		5.1
2,019	10.2		10.2
2,020	10.2		10.2
2,021	10.2		10.2
2,022	$ 9.3		$ 9.3
Minimum
Finite-Lived Intangible Assets [Line Items]
Finite-Lived intangible asset, useful life			5 years
Maximum
Finite-Lived Intangible Assets [Line Items]
Finite-Lived intangible asset, useful life			30 years

Goodwill and Intangible Asset73

Goodwill and Intangible Assets Schedule of Intangible Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	$ 215,130	$ 260,868
Accumulated amortization	(76,047)	(86,858)
Net carrying amount	139,083	174,010
Customer relationships
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	64,745	110,483
Accumulated amortization	(15,548)	(29,965)
Net carrying amount	49,197	80,518
Customer contracts
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	94,692	94,692
Accumulated amortization	(50,664)	(48,173)
Net carrying amount	44,028	46,519
Dedicated acreage
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	42,547	42,547
Accumulated amortization	(6,904)	(6,216)
Net carrying amount	35,643	36,331
Collaborative arrangements
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	11,884	11,884
Accumulated amortization	(1,839)	(1,415)
Net carrying amount	10,045	10,469
Noncompete agreements
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	1,064	1,064
Accumulated amortization	(1,064)	(1,064)
Net carrying amount	0	0
Other
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	198	198
Accumulated amortization	(28)	(25)
Net carrying amount	$ 170	$ 173

Investment in Unconsolidated 74

Investment in Unconsolidated Affiliates Partnership's Equity Investments (Details) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended
	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances		$ 348,434		$ 348,434
Earnings in unconsolidated affiliates	$ 10,446	23,119	$ 17,552	23,119	$ 32,954
Contributions		4,531
Distributions		(44,554)
Balances	$ 331,530			$ 331,530
FPS
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)	35.70%			35.70%		35.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances		90,412		$ 90,412
Earnings in unconsolidated affiliates				5,267
Contributions				826
Distributions				(6,246)
Balances	$ 90,259			$ 90,259
OGL
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)	35.70%			35.70%		35.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances		46,932		$ 46,932
Earnings in unconsolidated affiliates				3,916
Contributions				0
Distributions				(7,972)
Balances	$ 42,876			$ 42,876
Destin
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)	66.70%			66.70%		66.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances		124,245		$ 124,245
Earnings in unconsolidated affiliates				4,449
Contributions				0
Distributions				(17,872)
Balances	$ 110,822			$ 110,822
Tri-State
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)	16.70%			16.70%		16.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances		53,057		$ 53,057
Earnings in unconsolidated affiliates				1,880
Contributions				0
Distributions				(3,316)
Balances	$ 51,621			$ 51,621
Okeanos
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)	66.70%			66.70%		66.70%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances		22,445		$ 22,445
Earnings in unconsolidated affiliates				4,781
Contributions				0
Distributions				(8,010)
Balances	$ 19,216			$ 19,216
Wilprise
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)	25.30%			25.30%		25.30%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances		4,689		$ 4,689
Earnings in unconsolidated affiliates				510
Contributions				0
Distributions				(538)
Balances	$ 4,661			$ 4,661
Cayenne JV
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)	50.00%			50.00%		50.00%
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Balances		$ 6,654		$ 6,654
Earnings in unconsolidated affiliates				2,316
Contributions				3,705
Distributions				(600)
Balances	$ 12,075			$ 12,075

Investment in Unconsolidated 75

Investment in Unconsolidated Affiliates Financial Information for the Partnership's Equity Investments - Balance Sheets (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Equity Method Investments and Joint Ventures [Abstract]
Current assets	$ 65,283	$ 80,405
Non-current assets	1,272,593	1,288,862
Current liabilities	117,591	130,904
Non-current liabilities	$ 447,654	$ 436,584

Investment in Unconsolidated 76

Investment in Unconsolidated Affiliates Financial Information for the Partnership's Equity Investments - Statement of Operations (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Aug. 31, 2017	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Equity Method Investments and Joint Ventures [Abstract]
Revenue		$ 51,790	$ 105,373	$ 108,689	$ 203,366
Operating expenses		8,213	25,781	14,507	51,977
Net income		$ 27,303	$ 76,414	$ 60,149	$ 145,532
POGS
Schedule of Equity Method Investments [Line Items]
Percent interest acquired	100.00%

Accrued Expenses and Other Cu77

Accrued Expenses and Other Current Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Other Liabilities Disclosure [Abstract]
Capital expenditures	$ 8,137	$ 10,721
Accrued interest	6,485	3,190
Convertible preferred unit distributions	8,474	0
Current portion of asset retirement obligation	6,416	6,416
Additional Blackwater acquisition consideration	5,000	5,000
Taxes payable	3,676	5,263
Due to related parties	5,225	6,609
Royalties, gas imbalance and leases payables	6,423	7,905
Professional fees	4,566	1,848
Other	12,993	21,902
Total accrued expenses and other current liabilities	$ 67,395	$ 68,854

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2018	Dec. 31, 2017
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Non-current balance	$ 66,194
Current balance	6,416
Balances at December 31, 2017	72,610
Additions	260
Expenditures	(7)
Accretion expense	911
Balances at June 30, 2018	72,610	$ 73,774	$ 72,610
Less: current portion	6,416
Noncurrent asset retirement obligation	$ 67,358
Restricted cash and cash equivalents		$ 5,000	$ 5,000

Debt Obligations (Details)

Debt Obligations (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Long-term	$ 1,290,706	$ 1,218,238
Unamortized debt issuance costs	(9,020)	(9,231)
Total debt obligations	1,281,686	1,209,007
Less: current portion	(3,624)	(7,551)
Long-term debt	1,278,062	1,201,456
Senior Notes | 8.50% Senior Notes
Debt Instrument [Line Items]
Long-term	$ 425,000	$ 425,000
Debt instrument, stated interest rate (percent)	8.50%	8.50%
Senior Notes | 3.77% Senior Notes
Debt Instrument [Line Items]
Long-term	$ 57,679	$ 58,324
Debt instrument, stated interest rate (percent)	3.77%	3.77%
Senior Notes | 3.97% Trans-Union Secured Senior notes
Debt Instrument [Line Items]
Long-term	$ 31,148	$ 32,025
Debt instrument, stated interest rate (percent)	3.97%	3.97%
Other debt
Debt Instrument [Line Items]
Long-term	$ 579	$ 4,989
Revolving Credit Facility
Debt Instrument [Line Items]
Revolving credit facility	$ 776,300	$ 697,900

Debt Obligations (Narrative) (D

Debt Obligations (Narrative) (Details)	Jun. 29, 2018USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2017	Dec. 31, 2017
Amendment to Original Credit Agreement
Debt Instrument [Line Items]
Line of credit facility, current borrowing capacity	$ 900,000,000
Required prepayment, percentage of cash proceeds of defined disposal		100.00%
Required prepayment, cash proceeds threshold for undefined disposal		$ 5,000,000
Reduction of borrowing capacity upon disposal		$ 200,000,000
Reduction of borrowing capacity upon disposal, percentage of cash proceeds of disposal		50.00%
Reduction of borrowing capacity, threshold for undefined disposition		$ 15,000,000
Reduction of borrowing capacity, percentage of cash proceeds of undefined disposal		25.00%
Borrowings outstanding		$ 776,300,000
Letters of credit outstanding, amount		39,000,000
Available borrowing capacity		71,600,000
Remaining borrowing capacity with conditional increase		$ 84,700,000
Weighted average interest rate on borrowings under facility		5.81%	4.67%
Amendment to Original Credit Agreement | Maximum
Debt Instrument [Line Items]
Consolidated Total Leverage Ratio	5
Amendment to Original Credit Agreement | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	3.50%
8.50% Senior Notes | Senior Notes
Debt Instrument [Line Items]
Debt instrument, stated interest rate (percent)		8.50%		8.50%

Debt Obligations (Financial Cov

Debt Obligations (Financial Covenants) (Details)	6 Months Ended
	Jun. 30, 2018
Amendment to Original Credit Agreement | Maximum
Debt Instrument [Line Items]
Ratio of indebtedness to net capital, after allowed acquisition	5.50
Revolving Credit Facility
Debt Instrument [Line Items]
Minimum Consolidated Interest Coverage Ration, Actual	3.11
Maximum Allowable Consolidated Total Leverage Ratio, Actual	5.42
Maximum Allowable Consolidated Secured Leverage Ratio, Actual	3.50
June 30, 2018 | Revolving Credit Facility
Debt Instrument [Line Items]
Consolidated Interest Coverage Ratio	2.50
Consolidated Secured Leverage Ratio	6.15
Consolidated Total Leverage Ratio	4
September 30, 2018 | Revolving Credit Facility
Debt Instrument [Line Items]
Consolidated Interest Coverage Ratio	2
Consolidated Secured Leverage Ratio	6.25
Consolidated Total Leverage Ratio	3.75
December 31, 2018 | Revolving Credit Facility
Debt Instrument [Line Items]
Consolidated Interest Coverage Ratio	1.75
Consolidated Secured Leverage Ratio	5.50
Consolidated Total Leverage Ratio	3.50
March 31, 2019 | Revolving Credit Facility
Debt Instrument [Line Items]
Consolidated Interest Coverage Ratio	1.75
Consolidated Secured Leverage Ratio	5
Consolidated Total Leverage Ratio	3.50
June 30, 2019 and thereafter | Revolving Credit Facility
Debt Instrument [Line Items]
Consolidated Interest Coverage Ratio	2
Consolidated Secured Leverage Ratio	5
Consolidated Total Leverage Ratio	3.50

Debt Obligation, Redemption Pri

Debt Obligation, Redemption Prices (Details) - Senior Notes - 8.50% Senior Notes	6 Months Ended
	Jun. 30, 2018
2,018
Debt Instrument [Line Items]
Redemption price (percent)	104.25%
2,019
Debt Instrument [Line Items]
Redemption price (percent)	102.125%
2020 and thereafter
Debt Instrument [Line Items]
Redemption price (percent)	100.00%

Convertible Preferred Units (Sc

Convertible Preferred Units (Schedule of Convertible Preferred Units) (Details) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended	6 Months Ended
	Mar. 31, 2018	Jun. 30, 2018	Jun. 30, 2017
Increase (Decrease) in Partners' Capital [Roll Forward]
Convertible preferred units, Beginning Balance, Amount,	$ 317,180	$ 317,180
Paid in kind unit distributions, Amount		60,883	$ 64,168
Convertible preferred units, Ending Balance, Amount,		$ 317,180
Unit Distributions
Increase (Decrease) in Partners' Capital [Roll Forward]
Paid in kind unit distributions, Amount	$ 0
Series A
Increase (Decrease) in Partners' Capital [Roll Forward]
Convertible preferred units, Beginning Balance, Units	10,719	10,719
Convertible preferred units, Ending Balance, Units		11,010
Convertible preferred units, Beginning Balance, Amount,	$ 191,798	$ 191,798
Convertible preferred units, Ending Balance, Amount,		$ 191,798
Series A | Unit Distributions
Increase (Decrease) in Partners' Capital [Roll Forward]
Paid in kind unit distributions, Units		291
Paid in kind unit distributions, Amount		$ 0
Series C
Increase (Decrease) in Partners' Capital [Roll Forward]
Convertible preferred units, Beginning Balance, Units	8,965	8,965
Convertible preferred units, Ending Balance, Units		9,242
Convertible preferred units, Beginning Balance, Amount,	$ 125,382	$ 125,382
Convertible preferred units, Ending Balance, Amount,		$ 125,382
Series C | Unit Distributions
Increase (Decrease) in Partners' Capital [Roll Forward]
Paid in kind unit distributions, Units		277
Paid in kind unit distributions, Amount		$ 0

Convertible Preferred Units (De

Convertible Preferred Units (Details)	Apr. 25, 2016$ / sharesshares	Jul. 27, 2015USD ($)$ / shares	Apr. 15, 2013USD ($)$ / sharesshares	Jun. 30, 2018USD ($)$ / sharesshares	Dec. 31, 2015USD ($)shares	Dec. 31, 2017shares
Series A
Preferred Units [Line Items]
Sale of units percentage			90.00%
Partners' Capital Account, Units | shares			5,142,857	11,010,000		10,719,000
Distribution per unit			$ 0.4125
Conversion price (usd per share)				$ 15.11
Conversion ratio				1.1582
Series A | High Point Infrastructure Partners, LLC
Preferred Units [Line Items]
Issuance of units | $			$ 15,000,000
Series A-2
Preferred Units [Line Items]
Conversion price (usd per share)				$ 15.11
Conversion ratio				1.1582
Aggregate proceeds | $					$ 45,000,000
Investment options, exercise price (in usd per share)		$ 17.50
Call right defined acquisition value | $		$ 100,000,000
Series A-2 | Magnolia Infrastructure Partners, LLC | Issuance of Preferred Units
Preferred Units [Line Items]
Units issued (in shares) | shares					2,571,430
Series C
Preferred Units [Line Items]
Partners' Capital Account, Units | shares				9,242,000		8,965,000
Conversion price (usd per share)				$ 13.28
Conversion ratio				1.0542
Investment options, exercise price (in usd per share)	$ 14
Shares issued upon conversion (in shares) | shares	1
Class of warrant, number of securities called by warrants (in shares) | 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
Expected dividend rate				18.00%
Fair value assumptions, expected volatility rate				42.00%
Issuance of warrant | $				$ 4,500,000
Series C | ArcLight | Issuance of Preferred Units
Preferred Units [Line Items]
Units issued (in shares) | shares	8,571,429

Partners Capital (Narrative) (D

Partners Capital (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Jul. 27, 2018	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Class of Stock [Line Items]
General partner interest				1.30%
Limited partner interests				98.70%
General partner interest, period distribution amount					$ 3.9
General partner interest, units issued (in shares)		965,000		965,000		965,000
Distribution declared per common unit (in usd per share)		$ 0.1031	$ 0.4125	$ 0.5156	$ 0.8250
Fair Value input, distribution growth rate				1.00%
Subsequent Event
Class of Stock [Line Items]
Distribution declared per common unit (in usd per share)	$ 0.1031
Minimum
Class of Stock [Line Items]
Fair value input, option value (dollars per unit)				$ 0.31
Fair value inputs, discount rate (percent)				5.80%
Maximum
Class of Stock [Line Items]
Fair value input, option value (dollars per unit)				$ 2.05
Fair value inputs, discount rate (percent)				6.23%
Series A
Class of Stock [Line Items]
Minimum cumulative distributions obligated to pay each quarter (dollars per unit)				$ 0.4125
Series C
Class of Stock [Line Items]
Minimum cumulative distributions obligated to pay each quarter (dollars per unit)				$ 0.4125
General Partner
Class of Stock [Line Items]
General partner interest, units issued (in shares)		300	272,811	300	272,811

Partners_ Capital Outstanding U

Partners’ Capital Outstanding Units (Details) shares in Thousands	6 Months Ended
	Jun. 30, 2018shares
Increase (Decrease) in Partners' Capital [Roll Forward]
Balances at December 31, 2017	965
Balances at December 31, 2017	52,711
Balances at June 30, 2018	965
Balances at June 30, 2018	52,972
General Partner | LTIP
Increase (Decrease) in Partners' Capital [Roll Forward]
Partners' Capital Account Increase	0
Limited Partner | LTIP
Increase (Decrease) in Partners' Capital [Roll Forward]
Partners' Capital Account Increase	261

Partners' Capital (Distribution

Partners' Capital (Distributions Declared and Paid) (Details) - USD ($) $ / shares in Units, $ in Thousands	May 15, 2018	Feb. 14, 2018
Distribution Made to Limited Partner [Line Items]
Cash Distributions	$ 22,140	$ 22,035
Cash Distributions Per Common Unit (dollars per unit)	$ 0.4125	$ 0.4125
General Partner
Distribution Made to Limited Partner [Line Items]
Cash Distributions	$ 287	$ 290
Limited Partner
Distribution Made to Limited Partner [Line Items]
Cash Distributions	$ 21,853	$ 21,745

Partners_ Capital Distributions

Partners’ Capital Distributions (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Sep. 30, 2018	Jun. 30, 2018	Sep. 30, 2017	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Class of Stock [Line Items]
General Partner's distribution					$ 60,883	$ 64,168
Limited Partner
Class of Stock [Line Items]
General Partner's distribution					60,088	63,574
General Partner
Class of Stock [Line Items]
General Partner's distribution					795	594
Cash Paid
Class of Stock [Line Items]
General Partner's distribution		$ 30,494		$ 28,298	52,529	60,494
Cash Paid | Limited Partner
Class of Stock [Line Items]
General Partner's distribution		21,853		21,390	43,598	46,303
Distributions declared			$ 21,400
Cash Paid | Limited Partner | Scenario, Forecast
Class of Stock [Line Items]
Distributions declared	$ 5,500
Cash Paid | General Partner
Class of Stock [Line Items]
General Partner's distribution		287		201	577	368
Distributions declared			$ 300
Cash Paid | General Partner | Scenario, Forecast
Class of Stock [Line Items]
Distributions declared	$ 100
Accrued
Class of Stock [Line Items]
General Partner's distribution		8,354		8,659	8,354	8,659
Paid-in-kind units
Class of Stock [Line Items]
General Partner's distribution		0		2,181	8,076	4,914
Series A | Cash Paid
Class of Stock [Line Items]
General Partner's distribution		4,542		2,117	4,542	4,644
Series A | Accrued
Class of Stock [Line Items]
General Partner's distribution		4,542		4,069	4,542	4,069
Series A | Paid-in-kind units
Class of Stock [Line Items]
General Partner's distribution		0		2,181	3,767	4,914
Series C | Cash Paid
Class of Stock [Line Items]
General Partner's distribution		3,812		3,627	3,812	7,254
Series C | Accrued
Class of Stock [Line Items]
General Partner's distribution		3,812		3,627	3,812	3,627
Series C | Paid-in-kind units
Class of Stock [Line Items]
General Partner's distribution		0		0	4,309	0
Series D | Cash Paid
Class of Stock [Line Items]
General Partner's distribution		0		963	0	1,925
American Midstream Partners L. P. | Series D | Accrued
Class of Stock [Line Items]
General Partner's distribution		$ 0		$ 963	$ 0	$ 963

Net Loss per Limited Partner 89

Net Loss per Limited Partner Unit Net Loss per Limited Partner Unit (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Loss from continuing operations	$ (17,274)	$ (25,901)	$ (31,116)	$ (54,072)
Less: Net income attributable to noncontrolling interests	13	1,462	57	2,765
Loss attributable to the Partnership	(17,287)	(27,363)	(31,173)	(56,837)
General Partner's distribution			60,883	64,168
General Partner's share in undistributed loss	(403)	(784)	(986)	(1,541)
Loss attributable to Limited Partners	(25,310)	(35,515)	(47,256)	(73,318)
Loss from discontinued operations, net of tax	0	(1,801)	0	(2,511)
Net loss attributable to Limited Partners	$ (25,310)	$ (37,316)	$ (47,256)	$ (75,829)
Weighted average number of common units outstanding: basic and diluted (shares)	52,969	51,870	52,869	51,870
Limited Partners' net loss per common unit - Basic and Diluted
Loss from continuing operations (in usd per unit)	$ (0.48)	$ (0.69)	$ (0.89)	$ (1.41)
Loss from discontinued operations (in usd per unit)	0	(0.03)	0	(0.05)
Net loss (in usd per share)	$ (0.48)	$ (0.72)	$ (0.89)	$ (1.46)
Potential common unit equivalents excluded from determination of diluted limited partners' net loss per common unit (in shares)	23,900	23,900	24,000	24,000
Series A
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Distributions	$ 4,542	$ 4,069	$ 9,084	$ 8,367
Series C
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Distributions	3,812	3,627	7,624	7,254
Series D
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Distributions	0	963	0	1,925
General Partner
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
General Partner's distribution			795	594
General Partner | Accrued
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
General Partner's distribution	$ 72	$ 277	$ 361	$ 476

Incentive Compensation (Narrati

Incentive Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Employer matching	$ 0.5	$ 0.4	$ 1.3	$ 0.9
LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common units available for future grants (shares)	3,665,180		3,665,180
Options granted (in shares)			0
Unrecognized compensation expense	$ 0.1		$ 0.1
LTIP | Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares)			809,357
Granted (in usd per share)			$ 8.56
Forfeited (in shares)			336,211
Forfeited (in usd per share)			$ 6.26
Vested (in shares)			253,245
Vested (in usd per share)			$ 5.87
Unrecognized compensation expense	10.2		$ 10.2
LTIP | Performance-based Awards (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares)			0
Unrecognized compensation expense	$ 5.6		$ 5.6

Incentive Compensation Incentiv

Incentive Compensation Incentive Compensation (Components of Equity-Based Compensation Expense) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity compensation expense			$ 2,194	$ 5,233
LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity compensation expense	$ 1,180	$ 1,196	2,194	5,233
LTIP | RSU
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity compensation expense	835	1,177	1,534	5,195
LTIP | PSU
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity compensation expense	330	0	630	0
LTIP | Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity compensation expense	$ 15	$ 19	$ 30	$ 38

Related Party Transactions (Na

Related Party Transactions (Narrative) (Details) - USD ($)	1 Months Ended	3 Months Ended	6 Months Ended		9 Months Ended
	Aug. 31, 2018	Jun. 30, 2018	Jun. 30, 2018	Jun. 30, 2017	Sep. 30, 2017	Dec. 31, 2017	Dec. 31, 2013
Related Party Transaction [Line Items]
Contributions			$ 23,264,000	$ 23,130,000
Revenue from related parties			1,300,000	1,200,000
Due from related parties		$ 6,773,000	6,773,000			$ 4,362,000
Other Current Assets
Related Party Transaction [Line Items]
Due from related parties		4,000,000	4,000,000			900,000
Blackwater
Related Party Transaction [Line Items]
Additional consideration							$ 5,000,000
Additional Blackwater acquisition consideration		5,000,000	5,000,000
General Partner
Related Party Transaction [Line Items]
Contributions			23,300,000
General Partner | Other Current Liabilities
Related Party Transaction [Line Items]
Due to Related Parties		5,200,000	5,200,000			$ 6,500,000
Consolidated Asset Management Services, LLC (CAMS) | Director
Related Party Transaction [Line Items]
Ownership interest (percent)						10.00%
Republic Midstream, LLC (“Republic”)
Related Party Transaction [Line Items]
Monthly fee					$ 100,000
Receivable balance from affiliate		100,000	100,000			$ 800,000
Affiliated Entity | Consolidated Asset Management Services, LLC (CAMS)
Related Party Transaction [Line Items]
Receivable balance from affiliate		0	0			0
Purchases from related party			200,000	200,000
Affiliated Entity | CIMA Energy Ltd
Related Party Transaction [Line Items]
Revenue from related parties			1,100,000	2,500,000
Purchases from related party			2,700,000	$ 2,600,000
Outstanding amounts due to/from related party		100,000	100,000			100,000
AMID Merger GP II, LLC
Related Party Transaction [Line Items]
Receivable balance from affiliate		2,500,000	$ 2,500,000			$ 2,500,000
Magnolia Infrastructure Partners, LLC
Related Party Transaction [Line Items]
Proceeds from additional capital contribution		$ 9,400,000
Scenario, Forecast | Magnolia Infrastructure Partners, LLC
Related Party Transaction [Line Items]
Proceeds from additional capital contribution	$ 8,300,000

Supplemental Cash Flow Inform93

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Limited Partners' Capital Account [Line Items]
Interest payments, net of capitalized interest	$ 36,778	$ 27,324
Increase (decrease) in accrued property, plant and equipment purchases	(2,584)	(3,131)
Accrued contributions to unconsolidated affiliates	(1,585)	0
Contributions	23,264	27,130
Accrued distributions on convertible preferred units	8,354	8,659
Paid-in-kind distributions on convertible preferred units	8,076	4,914
Limited Partner
Limited Partners' Capital Account [Line Items]
Contributions	$ 0	$ 4,000

Reportable Segments (Details)

Reportable Segments (Details) $ in Thousands	3 Months Ended			6 Months Ended
	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)segments	Jun. 30, 2017USD ($)
Segment Reporting, Revenue Reconciling Item [Line Items]
Number of reportable segments | segments				5
Segment information
Revenue	$ 220,572		$ 161,831	$ 426,340	$ 325,544
Gain on commodity derivatives, net	(355)		199	(296)	564
Total revenue	220,217		162,030	426,044	326,108
Cost of Sales	161,508		115,020	311,674	230,488
Direct operating expenses	21,742		18,709	45,189	36,114
Corporate expenses	23,372		27,374	46,064	57,487
Depreciation, amortization and accretion	21,236		26,483	43,234	52,053
Gain on sale of assets, net	0		18	(95)	(3)
Total operating expenses	227,858		187,604	446,066	376,139
Operating income (loss)	(7,641)		(25,574)	(20,022)	(50,031)
Interest expense	(19,691)		(17,122)	(33,567)	(35,078)
Other income (expense), net	169		0	191	(37)
Earnings in unconsolidated affiliates	10,446	$ 23,119	17,552	23,119	32,954
Loss from continuing operations before income taxes	(16,717)		(25,144)	(30,279)	(52,192)
Income tax expense	(557)		(757)	(837)	(1,880)
Loss from continuing operations	(17,274)		(25,901)	(31,116)	(54,072)
Loss from discontinued operations	0		(1,801)	0	(2,511)
Net loss	(17,274)		(27,702)	(31,116)	(56,583)
Less: Net income attributable to noncontrolling interests	13		1,462	57	2,765
Net loss attributable to the Partnership	(17,287)		(29,164)	(31,173)	(59,348)
Gas Gathering and Processing Services
Segment information
Revenue	49,509
Gain on commodity derivatives, net	(294)			(292)
Total revenue	49,215			84,893
Earnings in unconsolidated affiliates	0
Liquid Pipelines and Services
Segment information
Gain on commodity derivatives, net	(61)			(4)
Total revenue	120,556			240,384
Natural Gas Transportation Services
Segment information
Gain on commodity derivatives, net	0			0
Total revenue	15,567			31,629
Offshore Pipelines and Services
Segment information
Gain on commodity derivatives, net	0			0
Total revenue	18,519			35,380
Terminalling Services
Segment information
Gain on commodity derivatives, net	0			0
Total revenue	16,360			33,758
Operating Segments | Gas Gathering and Processing Services
Segment information
Revenue			39,307	85,185	73,714
Gain on commodity derivatives, net			(98)	(292)	(105)
Total revenue	49,215		39,209	84,893	73,609
Cost of Sales	34,948		26,582	58,003	49,769
Direct operating expenses	0		0	0	0
Total operating expenses
Operating income (loss)
Earnings in unconsolidated affiliates			0	0	0
Loss from continuing operations before income taxes
Segment gross margin	14,539		12,651	27,193	23,902
Operating Segments | Liquid Pipelines and Services
Segment information
Revenue	120,617		83,157	240,388	166,568
Gain on commodity derivatives, net	(61)		297	(4)	669
Total revenue	120,556		83,454	240,384	167,237
Cost of Sales	115,193		78,101	229,998	156,386
Direct operating expenses	0		0	0	0
Total operating expenses
Operating income (loss)
Earnings in unconsolidated affiliates	2,485		1,482	4,706	2,569
Loss from continuing operations before income taxes
Segment gross margin	7,744		6,765	15,014	13,401
Operating Segments | Natural Gas Transportation Services
Segment information
Revenue	15,567		11,397	31,629	23,835
Gain on commodity derivatives, net	0		0	0	0
Total revenue	15,567		11,397	31,629	23,835
Cost of Sales	5,839		5,678	11,126	11,938
Direct operating expenses	0		0	0	0
Total operating expenses
Operating income (loss)
Earnings in unconsolidated affiliates	0		0	0	0
Loss from continuing operations before income taxes
Segment gross margin	9,653		5,631	20,340	11,750
Operating Segments | Offshore Pipelines and Services
Segment information
Revenue	18,519		12,139	35,380	26,970
Gain on commodity derivatives, net	0		0	0	0
Total revenue	18,519		12,139	35,380	26,970
Cost of Sales	2,150		2,586	4,146	5,929
Direct operating expenses	0		0	0	0
Total operating expenses
Operating income (loss)
Earnings in unconsolidated affiliates	7,961		16,070	18,413	30,385
Loss from continuing operations before income taxes
Segment gross margin	24,330		25,623	49,647	51,426
Operating Segments | Terminalling Services
Segment information
Revenue	16,360		15,831	33,758	34,457
Gain on commodity derivatives, net	0		0	0	0
Total revenue	16,360		15,831	33,758	34,457
Cost of Sales	3,378		2,073	8,401	6,466
Direct operating expenses	4,131		2,998	8,453	6,071
Total operating expenses
Operating income (loss)
Earnings in unconsolidated affiliates	0		0	0	0
Loss from continuing operations before income taxes
Segment gross margin	$ 8,851		$ 10,760	$ 16,904	$ 21,920

Reportable Segments - Assets (D

Reportable Segments - Assets (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Segment Reporting Information [Line Items]
Assets	$ 1,941,327		$ 1,941,327		$ 1,923,466
Investments in unconsolidated affiliates	331,530		331,530		348,434
Total capital expenditures	30,590	$ 22,943	56,533	$ 41,888
Gas Gathering and Processing Services
Segment Reporting Information [Line Items]
Assets	388,147		388,147		404,872
Total capital expenditures	6,657	4,143	13,311	8,526
Liquid Pipelines and Services
Segment Reporting Information [Line Items]
Assets	374,668		374,668		359,646
Investments in unconsolidated affiliates	68,357		68,357		64,399
Total capital expenditures	4,767	1,005	11,180	1,376
Offshore Pipelines and Services
Segment Reporting Information [Line Items]
Assets	521,710		521,710		553,213
Investments in unconsolidated affiliates	263,173		263,173		284,035
Total capital expenditures	14,004	1,611	20,354	1,134
Natural Gas Transportation Services
Segment Reporting Information [Line Items]
Assets	266,972		266,972		268,991
Total capital expenditures	1,154	14,138	2,492	24,366
Terminalling Services
Segment Reporting Information [Line Items]
Assets	289,226		289,226		293,085
Total capital expenditures	2,416	1,031	6,122	2,841
Other Segments
Segment Reporting Information [Line Items]
Assets	100,604		100,604		$ 43,659
Total capital expenditures	$ 1,592	1,015	$ 3,074	3,645
Propane Business
Segment Reporting Information [Line Items]
Total capital expenditures		$ 1,300		$ 2,200

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Millions	Aug. 01, 2018	Jul. 31, 2018	Jul. 27, 2018	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Subsequent Event [Line Items]
Distribution declared per common unit (in usd per share)				$ 0.1031	$ 0.4125	$ 0.5156	$ 0.8250
Subsequent Event
Subsequent Event [Line Items]
Distribution declared per common unit (in usd per share)			$ 0.1031
Distribution made to limited partner, distributions declared, per unit, annualized basis (in usd per share)			$ 0.4125
Payments for termination fee	$ 17
Subsequent Event | Marine Products
Subsequent Event [Line Items]
Proceeds from sale of business and assets, net of cash on hand		$ 208.6
Advisory fees and other costs		$ 5.7

Uncategorized Items - amid-2018

Label	Element	Value
Restricted Cash, Current	us-gaap_RestrictedCashCurrent	$ 0
Restricted Cash, Current	us-gaap_RestrictedCashCurrent	20,352,000
Restricted Cash, Noncurrent	us-gaap_RestrictedCashNoncurrent	323,564,000
Restricted Cash, Noncurrent	us-gaap_RestrictedCashNoncurrent	$ 5,045,000