Southcross Energy Partners 10-K 9 Mar 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information	12 Months Ended
	Dec. 31, 2016USD ($)shares
Document and Entity Information
Entity Registrant Name	Southcross Energy Partners, L.P.
Entity Central Index Key	1,547,638
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Smaller Reporting Company
Entity Public Float | $	$ 44,038,384,000
Entity Common Stock, Shares Outstanding | shares	48,502,090
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 21,226,000	$ 11,348,000
Trade accounts receivable	51,894,000	39,585,000
Accounts Receivable, Related Parties	7,976,000	49,734,000
Prepaid expenses	2,751,000	3,915,000
Other current assets	4,343,000	1,256,000
Property, plant and equipment, net	971,286,000	1,066,001,000
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	124,096,000	140,526,000
Other Assets, Noncurrent	2,504,000	6,595,000
Intangible assets, net	1,400,000	1,500,000
Total assets	1,186,076,000	1,318,960,000
Current liabilities:
Accounts payable and accrued liabilities	50,639,000	66,458,000
Due to Affiliate, Current	524,000	7,871,000
Other Long-term Debt, Current	4,500,000	4,500,000
Other current liabilities	10,976,000	10,406,000
Total current liabilities	66,639,000
Long-term debt	543,872,200	604,518,000
Other non-current liabilities	11,936,000	3,871,000
Total liabilities	622,447,000
Partners' capital:
Total partners' capital	563,629,000	621,336,000
Liabilities, preferred units, partners' capital and members' equity:
Total liabilities, preferred units and partners' capital	1,186,076,000
Common Units
Partners' capital:
Total partners' capital	255,124,000	271,236,000
Class B Convertible Units [Member]
Partners' capital:
Total partners' capital	278,508,000	300,596,000
Subordinated Limited Partners [Member]
Partners' capital:
Total partners' capital	19,240,000	37,920,000
General Partner Units [Member]
Partners' capital:
General Partner interest	10,757,000	11,584,000
Partners' capital:
Total partners' capital	$ 10,757,000	$ 11,584,000

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Dec. 31, 2015	Dec. 31, 2014
Common Units
Partners' capital:
Limited Partner, units outstanding	23,800,943	12,253,985
Subordinated Limited Partners [Member]
Partners' capital:
Limited Partner, units outstanding	12,213,713	12,213,713
Redeemable
Partners' capital:
Series A convertible preferred units issued	14,889,078	1,769,915
Series A convertible preferred units outstanding	14,889,078	1,769,915

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Document Period End Date	Dec. 31, 2016
Revenue from Related Parties	$ 97,500	$ 94,700
Revenues:	548,723	698,473
Expenses:
Depreciation and amortization	(106,947)	(70,814)
Asset Impairment Charges	476	7,067
Income (Loss) from Equity Method Investments	(21,123)	(13,452)
Loss on extinguishment of debt	1,006	0
Gain on legal settlement	3,939	0
Net loss	94,948	55,493
Net loss attributable to partners	(94,995)	(51,399)
Less deemed dividend on:
Net income (loss) allocated to limited partners	$ (94,948)	$ (55,493)
Earnings per unit:
Basic and diluted net loss per Southcross Energy LLC common unit	$ (1.48)	$ (0.93)
General Partner [Member]
Expenses:
Net loss	$ 1,911	$ 1,084
Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure	47	164
Common Units
Less deemed dividend on:
Net loss attributable to Southcross Energy LLC common unitholders	(50,612)	(24,790)
Net income (loss) allocated to limited partners	(50,612)	(24,790)
Subordinated Limited Partners [Member]
Less deemed dividend on:
Net income (loss) allocated to limited partners	(18,089)	(11,300)
Southcross Holdings Common [Member]
Expenses:
Net loss attributable to partners	$ 0	$ (4,258)

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Statement of Comprehensive Income [Abstract]
Net loss	$ (94,948)	$ (55,493)

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Cash flows from operating activities:
Net loss	$ (94,948)	$ (55,493)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization	106,947	70,814
Unit-based compensation	3,523	4,573
Loss on extinguishment of debt	(1,006)	0
Amortization of Financing Costs and Discounts	3,614	3,494
Loss (gain) on sale of assets, net	11,768	(416)
Unrealized (gain) loss	147	(110)
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions	(21,123)	(13,452)
Proceeds from Equity Method Investment, Dividends or Distributions	740	500
Asset Impairment Charges	476	7,067
Gain on legal settlement, Formosa	(2,375)	0
Other, net	(310)	(82)
Changes in operating assets and liabilities:
Trade accounts receivable, including affiliates	(31,554)	3,069
Prepaid expenses and other current assets	(947)	495
Other non-current assets	358	(296)
Accounts payable and accrued liabilities	(18,234)	(24,559)
Other liabilities, including affiliates	9,112	1,701
Net cash provided by operating activities	50,902	18,725
Cash flows from investing activities:
Capital expenditures	(26,066)	(108,698)
Expenditures for assets subject to property damage claims, net of insurance proceeds and deductibles	(125)	(78)
Proceeds from Sale of Productive Assets	22,470	4,693
Payments to Acquire Interest in Joint Venture	(5,433)	(8,910)
Payments to Acquire Businesses and Interest in Affiliates	0	(15,000)
Net cash used in investing activities	(8,904)	(127,837)
Cash flows from financing activities:
Proceeds from Lines of Credit	11,210	187,695
Repayments under our credit facility	(70,350)	(36,000)
Repayments of Long-term Debt	(4,500)	(4,500)
Payments on capital lease obligations	(419)	(528)
Financing costs	(1,366)	(698)
Proceeds from Issuance of Preferred Stock and Preference Stock	(138)
Proceeds from Partnership Contribution	0	1,301
Proceeds from (Payments for) Other Financing Activities	29,416	0
Payments of distributions and distribution equivalent rights	0	(46,915)
Proceeds from (Repayments of) Related Party Debt	14,000	0
Repayments of Notes Payable	(14,260)	0
Affiliate Costs	0	17,858
Related Party Transaction Reimbursement Expenses from Transactions with Related Party	4,053	1,023
Increase (Decrease) in Other Financing Activities	234	(425)
Net cash provided by financing activities	(32,120)	118,811
Cash and Cash Equivalents, Period Increase (Decrease)	9,878	9,699
Cash and cash equivalents — Beginning of year	11,348	1,649
Cash and cash equivalents — End of year	21,226	11,348
Common Units
Cash flows from financing activities:
Tax withholdings on unit-based compensation vested units	(138)
General Partner [Member]
Cash flows from operating activities:
Net loss	$ (1,911)	$ (1,084)

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL AND MEMBERS' EQUITY - USD ($) $ in Thousands	Total	Class B Convertible Units [Member]	Southcross Holdings Common [Member]	General Partner [Member]	General Partner [Member]Class B Convertible Units [Member]	Common Units	Common UnitsClass B Convertible Units [Member]	Common UnitsCommon Units [Member]	Class B Convertible Units [Member]	Class B Convertible Units [Member]Class B Convertible Units [Member]	Subordinated Limited Partners [Member]	Subordinated Limited Partners [Member]Class B Convertible Units [Member]	Subordinated Limited Partners [Member]Subordinated Units [Member]	Southcross Holdings Common [Member]	valley wells [Member]	valley wells [Member]Southcross Holdings Common [Member]	valley wells [Member]Common Units
Net income (loss) allocated to limited partners	$ (55,493)					$ (24,790)		$ (24,730)	$ (14,225)		$ (11,300)		$ (11,256)
BALANCE-Partners' Capital at Dec. 31, 2014	697,104			$ 12,385		259,735			298,833		48,831					$ 77,320
Increase (Decrease) in Shareholders' Equity
Net loss	(55,493)			(1,084)					(14,225)
Series A convertible preferred unit in-kind distribution and fair value adjustments		$ 0			$ (162)		$ (5,340)		8,059	$ 8,059		$ (2,557)
Contributions from general partner	0			(165)		(112)					(53)
Deemed dividend on:
Preferred units	(1,301)			(1,301)
Purchase and retirement of Partnership common units	4,443					4,443
Distribution to partners	(46,915)			(1,750)		(41,733)					(3,432)
Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure				164
BALANCE-Partners' Capital at Dec. 31, 2015	621,336			11,584		271,236			300,596		37,920					0
Deemed dividend on:
Business Combination, Consideration Transferred	(15,000)		$ (77,640)
Accrued Distribution on Long Term Incentive Plan	718					(718)
Net Income (Loss) Allocated to General Partners				(1,024)										$ (4,258)
Adjustments Related to Tax Withholding for Share-based Compensation	(425)					(425)
Affiliate Costs	17,858														$ 2,670		$ 2,670
Payments to Acquire Businesses and Interest in Affiliates	15,000		15,000
Business Acquisition, Transaction Costs															$ 17,858	$ 17,858
Interest Receivable				75
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities	1,436		$ 1,436
Net income (loss) allocated to limited partners	(94,948)					(50,612)		$ (50,586)	(24,383)		(18,089)		$ (18,080)
Net loss	(94,948)			(1,911)					(24,383)
Series A convertible preferred unit in-kind distribution and fair value adjustments					$ 62		$ 1,654			$ (2,307)		$ 591
Contributions from general partner				(47)		26			12		9
Purchase and retirement of Partnership common units	3,523					3,523
Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure				47
BALANCE-Partners' Capital at Dec. 31, 2016	563,629			10,757		255,124			$ 278,508		$ 19,240
Deemed dividend on:
Accrued Distribution on Long Term Incentive Plan						(11)
Retention bonus funded by Holdings						936
Net Income (Loss) Allocated to General Partners				(1,899)
Affiliate Costs	0																$ 2,406
Payments to Acquire Businesses and Interest in Affiliates	0
Tax withholdings on unit-based compensation vested units						(138)
Equity contribution from Holdings	$ 30,270			854		$ 29,416
Interest Receivable				$ 233

ORGANIZATION AND DESCRIPTION OF

ORGANIZATION AND DESCRIPTION OF BUSINESS	12 Months Ended
	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
ORGANIZATION AND DESCRIPTION OF BUSINESS	ORGANIZATION, DESCRIPTION OF BUSINESS AND SIGNIFICANT ACCOUNTING POLICIES Organization and Description of Business Southcross Energy Partners, L.P. (the "Partnership," "Southcross," "we," "our" or "us") is a Delaware limited partnership formed in April 2012. Our common units are listed on the New York Stock Exchange under the symbol “SXE.” We are a master limited partnership, headquartered in Dallas, Texas, that provides natural gas gathering, processing, treating, compression and transportation services and NGL fractionation and transportation services. We also source, purchase, transport and sell natural gas and NGLs. Our assets are located in South Texas, Mississippi and Alabama and include two gas processing plants, one fractionation facility and gathering and transportation pipelines. Southcross Holdings LP, a Delaware limited partnership (“Holdings”), indirectly owns 100% of Southcross Energy Partners GP, LLC, a Delaware limited liability company, our General Partner (“General Partner”) (and therefore controls us), all of our subordinated and Class B convertible units and 54.6% of our common units. Our General Partner owns an approximate 2.0% interest in us and all of our incentive distribution rights. Following the emergence of Holdings from its Chapter 11 reorganization proceeding on April 13, 2016 (see Note 2), EIG Global Energy Partners, LLC (“EIG”) and Tailwater Capital LLC (“Tailwater”) (collectively, the “Sponsors”) each indirectly own approximately one-third of Holdings, and a group of consolidated lenders under Holdings' term loan (the "Lenders") own the remaining one-third of Holdings. Segments Our chief operating decision-maker is the Chief Executive Officer who reviews financial information presented on a consolidated basis in order to assess our performance and make decisions about resource allocations. There are no segment managers who are held accountable by the chief operating decision-maker, or anyone else, for operations, operating results and planning for levels or components below the consolidated unit level. Accordingly, we have determined that we have one reportable segment.

BASIS OF PRESENTATION

BASIS OF PRESENTATION	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
BASIS OF PRESENTATION	Basis of Presentation The accompanying consolidated financial statements and related notes present the consolidated balance sheets as of December 31, 2016 and 2015 and the consolidated statements of operations, cash flows and changes in partners' capital for the years ended December 31, 2016 and 2015. We recognized the 2015 Holdings Acquisition (defined in Note 3) at Holdings’ historical cost because the acquisition was executed by entities under common control. Thus, the difference between consideration paid and Holdings’ historical cost (net book value) at May 7, 2015, the date on which the 2015 Holdings Acquisition closed, was recorded as a reduction to partners’ capital. Due to the common control aspect, the 2015 Holdings Acquisition was accounted for by the Partnership on an “as if pooled” basis for the periods during which common control existed which began on August 4, 2014. See Note 3. The accompanying consolidated financial statements were prepared in accordance with accounting principles generally accepted in the U.S. ("GAAP") and in accordance with the rules and regulations of the U.S. Securities and Exchange Commission. Our consolidated financial statements include the accounts of Southcross and its 100% owned subsidiaries. We eliminate all intercompany balances and transactions in preparing consolidated financial statements. We evaluate events that occur after the balance sheet date, but before the financial statements are issued, for potential recognition or disclosure. Based on the evaluation, we determined that there were no material subsequent events for recognition or disclosure other than those disclosed in this report. See Note 15. Principles of Consolidation We consolidate entities when we have the ability to control or direct the operating and financial decisions of the entity or when we have a significant interest in the entity that gives us the ability to direct the activities that are significant to that entity. The determination of our ability to control, direct or exert significant influence over an entity involves the use of judgment. We do not have ownership in any consolidated variable interest entities. Use of Estimates The preparation of the consolidated financial statements in conformity with GAAP requires management to make various estimates and assumptions that may affect the amounts of assets and liabilities, disclosures of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the period. Actual results may differ from those estimates. Significant Accounting Policies Revenue Recognition Using the revenue recognition criteria of persuasive evidence of an exchange arrangement exists, delivery has occurred or services have been rendered and the price is fixed or determinable, we record natural gas and NGL sales revenue in the period when the physical product is delivered to the customer and in an amount based on the pricing terms of an executed contract. Our transportation, compression, processing, fractionation and other revenue is recognized in the period when the service is provided and represents our fee-based service revenue. In addition, collectability is evaluated on a customer-by-customer basis. New customers are subject to a credit review process, which evaluates the customers' financial position and their ability to pay. Our sale and purchase arrangements primarily are accounted for on a gross basis in the statements of operations. These transactions are contractual arrangements that establish the terms of the purchase of natural gas or NGLs at a specified location and the sale of natural gas or NGLs at a different location on the same or on another specified date. These transactions require physical delivery and transfer of the risk and reward of ownership are evidenced by title transfer, assumption of environmental risk, transportation scheduling, credit risk and counterparty nonperformance risk. We derive revenue in our business from the following types of arrangements: • Fixed-Fee. We receive a fixed-fee per unit of natural gas volume that we gather at the wellhead, process, treat, compress and/or transport for our customers, or we receive a fixed-fee per unit of NGL volume that we fractionate. Some of our arrangements also provide for a fixed-fee for guaranteed transportation capacity on our systems. • Fixed-Spread. Under these arrangements, we purchase natural gas and NGLs from producers or suppliers at receipt points on our systems at an index price plus or minus a fixed price differential and sell these volumes of natural gas and NGLs at delivery points off our systems at the same index price, plus or minus a fixed price differential. By entering into such back-to-back purchases and sales, we are able to mitigate our risk associated with changes in the general commodity price levels of natural gas and NGLs. We remain subject to variations in our fixed-spreads to the extent we are unable to precisely match volumes purchased and sold in a given time period or are unable to secure the supply or to produce or market the necessary volume of products at our anticipated differentials to the index price. • Commodity-Sensitive. In exchange for our processing services, we may remit to a customer a percentage of the proceeds from our sales, or a percentage of the physical volume, of residue natural gas and/or NGLs that result from our natural gas processing, or we may purchase NGLs from customers at set fixed NGL recoveries and retain the balance of the proceeds or physical commodity for our own account. These arrangements are generally combined with fixed-fee and fixed-spread arrangements for processing services and, therefore, represent only a portion of a processing contract's value. The revenues we receive from these arrangements directly correlate with fluctuating general commodity price levels of natural gas and NGLs and the volume of NGLs recovered relative to the fixed recovery obligations. Certain of our gathering and processing agreements provide for quarterly and annual minimum volume commitment ("MVC"). Under these MVCs, our customers agree to ship and/or process a minimum volume of production on our gathering systems or to pay a minimum monetary amount over certain periods during the term of the MVC. A customer must make a shortfall payment to us at the end of the contracted measurement period if its actual throughput volumes are less than its MVC for that period. Certain customers are entitled to utilize shortfall payments to offset gathering fees in one or more subsequent measurement periods to the extent that such customer's throughput volumes in a subsequent contracted measurement period exceed its MVC for that contracted measurement period. We recognize customer billings for obligations under their MVCs as revenue when the obligations are billable under the contract and the customer does not have the right to utilize shortfall payments to offset gathering fees in excess of its MVCs in subsequent periods. We record customer billings for obligations under their MVCs as deferred revenue when the customer has the right to utilize shortfall payments to offset gathering or processing fees in subsequent periods. We recognize deferred revenue under these arrangements in revenue once all contingencies or potential performance obligations associated with the related volumes have either (i) been satisfied through the gathering or processing of future excess volumes of natural gas, or (ii) expired (or lapsed) through the passage of time pursuant to the terms of the applicable natural gas gathering agreement. We classify deferred revenue as a current liability for arrangements where the expiration of a customer's right to utilize shortfall payments is 12 months or less. Long-Lived Assets Our property, plant and equipment is recorded at its original cost of construction or, upon acquisition, at fair value of the assets acquired. For assets we construct, we capitalize direct costs, such as labor and materials, and indirect costs, such as overhead and the cost of financing construction. Costs associated with obtaining rights of way agreements and easements to facilitate the building and maintenance of new pipelines are capitalized and depreciated over the life of the associated pipeline. We capitalize major units of property replacements or improvements and expense minor items. We use the straight-line method to depreciate property, plant and equipment over the estimated useful lives of the assets. We depreciate leasehold improvements and capital lease assets over the shorter of the life of the asset or the life of the lease. Maintenance and repairs are charged directly to expense as incurred, with the exception of substantial compression overhaul costs, which are capitalized and depreciated over the life of the overhaul. Our intangible assets consist of acquired long-term supply and gas gathering contracts. We amortize these contracts on a straight-line basis over the 30 -year expected useful lives of the contracts. Impairment of Long-Lived Assets We evaluate our long-lived assets by asset group, which include finite-lived intangible assets, for impairment when events or circumstances indicate that the asset group's carrying values may not be recoverable. These events include, but are not limited to, market declines that are believed to be other than temporary, changes in the manner in which we intend to use a long-lived asset or group, decisions to sell an asset and adverse changes in the legal or business environment such as adverse actions by regulators. If an event occurs, we evaluate the recoverability of our carrying value based on the long-lived asset group's ability to generate future cash flows on an undiscounted basis. If the undiscounted cash flows are not sufficient to recover the long-lived asset group's carrying value, or if we decide to sell a long-lived asset or group of assets, we adjust the carrying values of the asset downward, if necessary, to their estimated fair value. Our fair value estimates are based generally on assumptions market participants would use, including market data obtained through the sales process or an analysis of expected discounted cash flows. We had no impairment of our assets during the year ended December 31, 2016, but we recorded $0.5 million related to the write-off of software costs. During the year ended December 31, 2015, we recorded $7.1 million of impairment cost related primarily to a write-down of a spare turbine. Cash and Cash Equivalents We consider all short-term investments with an original maturity of three months or less to be cash equivalents. At December 31, 2016 and 2015, except for amounts held in bank accounts to cover current payables, all of our cash equivalents were invested in short-term money market accounts and overnight sweep accounts. Allowance for Doubtful Accounts In evaluating the collectability of our accounts receivable, we perform credit evaluations of our new customers and adjust payment terms based upon payment history and each customer's current creditworthiness, as determined by our review of such customer's credit information. We extend credit on an unsecured basis to many of our customers. In the event of a bankruptcy filing by a customer, we will determine if we will legally be able to collect any of the outstanding balance as a secured or unsecured creditor, and based on this determination we will reserve against part, or all, of the outstanding balance. We had an allowance for uncollectible accounts receivable of $0.1 million at December 31, 2015, which was written off during 2016. Asset Retirement Obligations We evaluate whether any future asset retirement obligations ("AROs") exist and estimate the costs for such AROs for certain future events. An ARO will be recorded in the periods where we can reasonably determine the settlement dates or the period in which the expense is incurred, and an estimated cost of the retirement obligation. Generally we do not have the intention of discontinuing the use of any significant assets or have a legal obligation to do so. Therefore, in these situations we do not have sufficient information to reasonably estimate any future AROs. No AROs were recorded for the years ended December 31, 2016 and 2015 . Environmental Costs and Other Contingencies We recognize liabilities for environmental and other contingencies when we have an exposure that indicates it is both probable that a liability has been incurred and the amount of loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue a liability for that amount. Where the most likely outcome cannot be estimated, a range of potential losses is established and no specific amount in that range is more likely than any other, the low end of the range is accrued. No amounts were recorded as of December 31, 2016. Fair Value of Financial Instruments Accounting guidance requires the disclosure of the fair value of all financial instruments that are not otherwise recorded at fair value in the financial statements. At December 31, 2016 and 2015 , financial instruments recorded at contractual amounts that approximate fair value include certain funds on deposit, accounts receivable, other receivables and accounts payable and accrued liabilities. The fair values of such items are not materially sensitive to shifts in market interest rates because of the short term to maturity of these instruments. See Note 5. Derivative Instruments In our normal course of business, we enter into month-ahead commodity swap contracts in order to hedge economically our exposure to certain intra-month natural gas index pricing risk. We manage our interest rate risk through interest rate swaps and interest rate caps. See Note 5. Derivative financial instruments are recorded in the consolidated balance sheets at fair value, except for derivative contracts that qualify for and for which we have elected the normal purchase or normal sale exceptions, which are not reflected in the consolidated balance sheets or statements of operations prior to accrual of the settlement. If they qualify, we present our derivative assets and liabilities on a net basis. We did not have any derivative financial instruments designated as fair value or cash flow hedges for accounting purposes during the years ended December 31, 2016 and 2015 . Changes in our derivative financial instruments' fair values are recognized immediately in earnings. We do not hold or issue financial instruments or derivative financial instruments for trading purposes. Unit-Based Compensation Unit-based awards which settle in common units are classified as equity and are recognized in the financial statements over the vesting period at their grant date fair value. Unit-based awards which settle in cash are classified as liabilities and remeasured at every balance sheet date through settlement, such that the vested portion of the liability is adjusted to reflect its revised fair value through compensation expense. Currently, all awards granted under the Amended and Restated 2012 Long-Term Incentive Plan (the “LTIP”) will be settled in common units. Compensation expense associated with unit-based awards, adjusted for forfeitures, is recognized evenly from the date of the grant over the vesting period within operations and maintenance and general and administrative expense on our consolidated statements of operations. Income Taxes No provision for federal or state income taxes, except as noted below, is included in our statements of operations as such income is taxable directly to our partners. Each partner is responsible for its share of federal and state income tax. Net earnings for financial statement purposes may differ significantly from taxable income reportable to each partner as a result of differences between the tax basis and financial reporting basis of assets and liabilities. We are subject to the Texas margin tax which qualifies as an income tax under GAAP that requires us to recognize the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis. Our current tax liability will be assessed based on the gross revenue apportioned to Texas. For the years ended December 31, 2016 and 2015 , there were no material temporary differences. Uncertain Tax Positions We evaluate the uncertainty in tax positions taken or expected to be taken in the course of preparing our consolidated financial statements to determine whether the tax positions are more likely than not of being sustained by the applicable tax authority. We believe that there are no uncertain tax positions and that no provision for income tax is required for these consolidated financial statements. As of December 31, 2016, tax years 2013 through 2016 remain subject to examination by the Internal Revenue Service and tax years 2012 through 2016 remain subject to examination by various state taxing authorities. Earnings per Unit Net loss per unit is calculated under the two-class method of computing earnings per unit when participating or multiple classes of securities exist. Under this method, undistributed earnings or losses for a period are allocated based on the contractual rights of each security to share in those earnings as if all of the earnings for the period had been distributed. Basic net loss per unit excludes dilution and is computed by dividing net loss attributable to limited partner common units by the weighted average number of limited partner common units outstanding during the period. Paid-in kind distributions are excluded from income available to common units in the calculation of basic earnings per unit. Dilutive net loss per unit reflects potential dilution from the potential issuance of limited partner common units. Dilutive net loss per unit is calculated using the treasury stock method. It is computed by dividing net loss attributable to limited partner common units by the weighted average number of limited partner common units outstanding during the period increased by the number of additional limited partner common units that would have been outstanding if the dilutive potential limited partner common units had been issued. Comprehensive Income (Loss) Comprehensive income (loss) is the same as net income (loss) for periods presented in the consolidated financial statements. Investments in Joint Ventures We own equity interests in three joint ventures with Targa Pipeline Partners LP as our joint venture partner. We own a 50% or less equity interest in each of the three entities. The joint venture arrangements give equal management rights with no single investor having unilateral control. Each party sharing joint control must consent to the ventures’ operating, investing and financing decisions. Therefore, because we do not have controlling financial interests, but do have significant influence, we use the equity method of accounting for investments in joint ventures. We recognize our share of the earnings and losses in the joint ventures pursuant to the terms of the applicable limited liability agreements governing such joint ventures, which provide for earnings and losses generally to be allocated based upon each member’s respective ownership interest in the joint ventures. We record our proportionate share of the joint ventures’ net income/loss as equity in income/losses of joint venture investments in the statements of operations. We evaluate investments in joint ventures for impairment when factors indicate that a decrease in the value of the investment has occurred that is not temporary. During the fourth quarter of 2016, as part of our cost-saving initiatives, management decided to significantly reduce the utilization of the T2 EF Cogeneration ("T2 Cogen") facility. In the immediate future, the T2 Cogen facility will only be utilized as a swing or backup facility for our Lone Star processing facility. As volumes are expected to increase in the ensuing years, management expects to need the generation capacity from the T2 Cogen facility to provide power to its Lone Star processing facility. As of December 31, 2016, management has no intention or plans to “mothball” or sell the T2 Cogen facility. See Note 13. Recent Accounting Pronouncements Accounting standard-setting organizations frequently issue new or revised accounting pronouncements. We review and evaluate new pronouncements and existing pronouncements to determine their impact, if any, on our consolidated financial statements. We are evaluating the impact of each pronouncement on our consolidated financial statements. Adopted Accounting Pronouncements In 2014, a new standard was issued that updated existing going concern guidance under GAAP. The new guidance relates to defining management’s responsibility to evaluate whether there is substantial doubt about an organization’s ability to continue as a going concern. Related disclosure in the notes to the consolidated financial statements are required surrounding whether it is probable that the entity will not be able to meet its obligations as they become due within one year after the date that financial statements are issued. We adopted this standard during the year ended December 31, 2016. See Note 2. In February 2015, the Financial Accounting Standards Board (“FASB”) issued a pronouncement that amended the consolidation guidance with regard to variable interest entities and voting interest entities. The standard became effective in 2016 and amended the guidance and framework for determining whether a partial-interest owner in a subsidiary should consolidate and potentially revise their disclosures about certain money market funds that are not within the scope of the variable interest entity guidance and the required transition disclosures in the fiscal period in which a change in accounting principle is made. We adopted this standard, which did not have a material impact to us, in 2016. New Accounting Pronouncements In February 2016, a pronouncement was issued amending disclosure and presentation requirements for lessees and lessors on the face of the balance sheet. The pronouncement states that a lessee should recognize a liability to make lease payments and a right-of-use asset representing its right to use the underlying asset for the lease term. When measuring assets and liabilities arising from a lease, a lessee (and a lessor) should include payments to be made in optional periods only if the lessee is reasonably certain to exercise an option to extend the lease or not to exercise an option to terminate the lease. Similarly, optional payments to purchase the underlying asset should be included in the measurement of lease assets and lease liabilities only if the lessee is reasonably certain to exercise that purchase option. In addition, also consistent with the previous leases guidance, a lessee (and a lessor) should exclude most variable lease payments in measuring lease assets and lease liabilities, other than those that depend on an index or a rate or are in substance fixed payments. This standard will become effective beginning in 2019. In March 2016, a pronouncement was issued amending the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities and classification on the statement of cash flows. This standard will become effective beginning in 2017. In March 2016, the FASB issued a pronouncement amending the requirement to adopt retroactively the equity method of accounting. The pronouncement eliminates the requirement that when an investment qualifies for use of the equity method as a result of an increase in the level of ownership interest or degree of influence, an investor must adjust the investment, results of operations, and retained earnings retroactively on a step-by-step basis as if the equity method had been in effect during all previous periods that the investment had been held. The new guidance requires that the equity method investor add the cost of acquiring the additional interest in the investee to the current basis of the investor’s previously held interest and adopt the equity method of accounting as of the date the investment becomes qualified for equity method accounting. Therefore, upon qualifying for the equity method of accounting, no retroactive adjustment of the investment is required. In addition, the pronouncement requires that an entity that has an available-for sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in accumulated other comprehensive income at the date the investment becomes qualified for use of the equity method. This standard will become effective beginning in 2017. In 2014, a comprehensive new revenue recognition standard that will supersede substantially all existing revenue recognition guidance under GAAP was issued. The standard's core principle is that a company will recognize revenue when it transfers promised goods or services to customers and in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. In April 2016, the FASB issued an accounting pronouncement which updates the identifying performance obligations and licensing implementation guidance. We are currently evaluating our contract mix, developing our implementation plan, and assessing the impact to our existing accounting policies and controls that will be impacted by the standard. The standard will become effective beginning in 2018. In May 2016, the FASB issued a pronouncement for the new revenue recognition guidance on assessing collectability, presentation of sales taxes, non-cash consideration, completed contracts and contract modifications. The pronouncement is intended to reduce the potential for diversity in practice at initial application and cost and complexity on an ongoing basis. The standard will become effective beginning in 2018. In August 2016, the FASB issued a pronouncement amending the presentation of how certain cash receipts and cash payments are presented and classified in the statement of cash flows. The standard will become effective at the beginning of 2018.

LIQUIDITY CONSIDERATIONS AND EQ

LIQUIDITY CONSIDERATIONS AND EQUITY OFFERINGS	12 Months Ended
	Dec. 31, 2016
Cash and Cash Equivalents [Abstract]
Liquidity Considerations and Equity Offerings	LIQUIDITY CONSIDERATIONS Our future cash flow will be materially adversely affected if the prices for natural gas, NGL and crude oil reduces the drilling for oil or natural gas in the geographic areas in which we operate, primarily the Eagle Ford Shale region. See Note 1 to our consolidated financial statements. The majority of our revenue is derived from fixed-fee and fixed-spread contracts, which have limited direct exposure to commodity price levels since we are paid based on the volumes of natural gas that we gather, process, treat, compress and transport and the volumes of NGLs we fractionate and transport, rather than being paid based on the value of the underlying natural gas or NGLs. In addition, a portion of our contract portfolio contains minimum volume commitment arrangements. The majority of our volumes are dependent upon the level of producer drilling activity. With the current price environment and reduction in drilling activity, we have begun to implement cost saving initiatives to improve future cash flows. In connection with Holdings' Chapter 11 reorganization, we entered into an equity cure contribution agreement (the “Equity Cure Agreement”) with Holdings that allowed us to cure any default under applicable Financial Covenants by having Holdings purchase equity interests in or make capital contributions to us, in an aggregate amount of up to $50 million (the "Contribution Amount"). In exchange for the Contribution Amount, we issued Holdings a number of our common units representing limited partner interests equal to, subject to certain exceptions, (i) the applicable Contribution Amount divided by (ii) a common unit reference price (“Reference Price”) equal to the volume weighted daily average price of the common units on the New York Stock Exchange (“VWAP”) calculated for a period of 15 trading days ending two trading days prior to the contribution by Holdings. Notwithstanding the VWAP calculation, the Reference Price would be no less than $0.89 per common unit and no greater than $1.48 per common unit (the “Range”), and if the VWAP was within the Range for a period of 15 trading days, the first of which was April 7, 2016, such VWAP would be the Reference Price for all common units issued in exchange for the Contribution Amount. The Equity Cure Agreement remained in place throughout 2016 and was used to fund equity cures totaling $12.4 million (excluding the $17.0 million discussed below) required to comply with the Consolidated Total Leverage Ratio of our Financial Covenants. See Note 10 for further discussion of our equity cure unit issuances. On July 25, 2016, we determined Holdings’ cash contribution to us for the first quarter 2016 equity cure had not been transferred to us timely, as required under the Third Amended and Restated Revolving Credit Agreement with Wells Fargo, N.A., UBS Securities LLC, Barclays Bank PLC and a syndicate of lenders (the "Third A&R Revolving Credit Agreement"), due to an administrative oversight, which resulted in a default. On July 26, 2016, Holdings fully funded the first quarter 2016 equity cure. On August 4, 2016, we entered into the limited waiver and second amendment to the Third A&R Revolving Credit Agreement whereby the lenders waived any default or right to exercise any remedy as a result of this technical event of default to fund timely the first quarter 2016 equity cure. On November 8, 2016, we entered into a limited waiver and third amendment to the Third A&R Revolving Credit Agreement (the “Third Amendment”), which stipulated, among other things, that (i) the equity cure funding deadline for the quarter ended September 30, 2016 (“Q3 2016 Equity Cure”) was extended from November 23, 2016 to December 16, 2016, and (ii) limited the total revolving credit exposure. On December 9, 2016, we entered into the fourth amendment to the Third A&R Revolving Credit Agreement (the "Fourth Amendment"), which stipulated, among other things, that (i) the deadline for funding the Q3 2016 Equity Cure was further extended from December 16, 2016 to January 12, 2017, and (ii) the Third A&R Revolving Credit Agreement was amended to require that any account into which we deposited funds, securities or commodities be subject to a lien and control agreement for the benefit of the secured parties under the Third A&R Revolving Credit Agreement. On December 29, 2016, we entered into the fifth amendment to the Third A&R Revolving Credit Agreement (the “Fifth Amendment”), pursuant to which we received a full waiver for all defaults or events of default arising out of our failure to comply with the financial covenant to maintain a Consolidated Total Leverage Ratio less than 5.00 to 1.00 for the quarter ended September 30, 2016. Additionally, pursuant to the Fifth Amendment, (i) the total aggregate commitments under the Third A&R Revolving Credit Agreement were reduced from $200 million to $145 million and the sublimit for letters of credit was also reduced from $75 million to $50 million (total aggregate commitments will be periodically further reduced through December 31, 2018); (ii) the Consolidated Total Leverage Ratio and Consolidated Senior Secured Leverage Ratio (periodically each of which is defined in the Fifth Amendment) financial covenants were suspended until the quarter ended March 31, 2019; and (iii) the Consolidated Interest Coverage Ratio (as defined in the Fifth Amendment) financial covenant requirement was reduced from 2.50 to 1.00 to 1.50 to 1.00 for all periods ending on or prior to December 31, 2018 (the “Ratio Compliance Date”). Prior to the Ratio Compliance Date, we will be required to maintain minimum levels of Consolidated EBITDA on a quarterly basis and be subject to certain covenants and restrictions related to liquidity and capital expenditures. See Note 7 to our consolidated financial statements. In connection with the execution of the Fifth Amendment, on December 29, 2016, the Partnership entered into (i) an Investment Agreement (the "Investment Agreement") with Holdings and Wells Fargo Bank, N.A., (ii) a Backstop Agreement (the "Backstop Agreement") with Holdings, Wells Fargo Bank, N.A. and the Sponsors and (iii) a First Amendment to Equity Cure Contribution Agreement (the "Equity Cure Contribution Amendment") with Holdings. Pursuant to the Equity Cure Contribution Amendment, on December 29, 2016, Holdings contributed $17.0 million to us in exchange for 11,486,486 common units. The proceeds of the $17.0 million contribution were used to pay down the outstanding balance under the Third A&R Revolving Credit Agreement and for general corporate purposes. In addition, pursuant to entering into the Investment Agreement, the previous Equity Cure Contribution Agreement with Holdings was terminated and Holdings has agreed to contribute $15.0 million to us (the “Committed Amount”) upon the earlier to occur of December 31, 2017 or notification from the Partnership of an event of default under the Third A&R Revolving Credit Agreement. In exchange for the amounts contributed pursuant to the Investment Agreement upon a Partial Investment Trigger or the Full Investment Trigger (as defined in the Investment Agreement), we will issue to Holdings, at Holdings’ election, either (i) a number of common units at an issue price equal to either (a) if the common units are listed on a national stock exchange, 93% of the volume weighted average price of such common units for the twenty day period immediately preceding the date of the contribution or (b) if the common units are not listed on a national stock exchange, the fair market value of such common units as reasonably agreed by us and Holdings or (ii) a senior unsecured note of the Partnership in an initial face amount equal to the amount of the contribution by Holdings (an “Investment Note”). If Holdings elects to receive an Investment Note in exchange for a contribution pursuant to the Investment Agreement, such Investment Note will mature on or after November 5, 2019 and bear interest at a rate of 12.5% per annum payable in-kind prior to December 31, 2018 and in cash on or after December 31, 2018. The Investment Notes, if any, will be our unsecured obligation to subordinate in right of payment to any of our secured obligations under the Third A&R Revolving Credit Agreement and will contain covenants and events of default no more restrictive than those currently provided in the Third A&R Revolving Credit Agreement. Pursuant to the Backstop Agreement, if Holdings is unable to satisfy its obligations under the Investment Agreement with cash on hand upon the occurrence of a Partial Investment Trigger or a Full Investment Trigger, the Sponsors have agreed to fund Holdings’ shortfall in providing the Committed Amount by contributing each Sponsor’s respective pro-rata portion of the shortfall to Holdings or, at the election of each Sponsor, directly to us. As consideration for any amounts contributed directly to us by a Sponsor pursuant to the Backstop Agreement, we will issue to such Sponsor the Common Units or Investment Note that would have otherwise been issued to Holdings under the Investment Agreement with respect to the amount contributed by the Sponsor. Based upon the Partnership financial forecast, amendments to the credit agreement (as discussed above), as well as the $15.0 million additional capital commitment from Holdings and the sponsors, we believe management's executed plans provide the Partnership with sufficient liquidity to fund future operations through at least twelve months from the date that these financial statements were issued.

ACQUISITIONS

ACQUISITIONS	12 Months Ended
	Dec. 31, 2015
Business Combinations [Abstract]
ACQUISITIONS	ACQUISITIONS Holdings Drop-Down Acquisition. On May 7, 2015, we completed the acquisition of gathering, treating, compression and transportation assets (the “2015 Holdings Acquisition”) consisting of the Valley Wells sour gas gathering and treating system (the "Valley Wells System"), compression assets that are part of the Valley Wells and Lancaster gathering and treating systems (the "Compression Assets") and two NGL pipelines pursuant to a Purchase, Sale and Contribution Agreement among Holdings, TexStar Midstream Utility, LP, Frio LaSalle Pipeline, LP (“Frio”), us and certain of our subsidiaries. Total consideration for the assets was $77.6 million , consisting of $15.0 million in cash and 4.5 million new common units, valued as of the date of closing and issued to Holdings. We also assumed the remaining capital expenditures for the completion of the NGL pipelines that were under construction. The 2015 Holdings Acquisition was deemed a transaction between entities under common control and, as such, was accounted for on an “as if pooled” basis for all periods which common control existed (which began on August 4, 2014). The Partnership’s financial results retrospectively include the financial results of the Valley Wells System and Compression Assets for all periods ending after August 4, 2014 and before May 7, 2015. The acquired NGL pipelines were accounted for as an asset acquisition and were included in the historical financial statements beginning on May 7, 2015. The amount of consideration paid below Holdings' net book value of the assets received and liabilities assumed of the 2015 Holdings Acquisition was recorded as an increase to partners' capital as summarized as follows (in thousands): Consideration paid (1) $ 77,640 Total net assets contributed 107,356 Net assets contributed in excess of consideration paid $ 29,716 Allocation of increase to partners' capital: Common limited partner interest $ 14,806 Class B Convertible limited partner interest 7,929 Subordinated limited partner interest 6,387 General Partner interest 594 Total increase to partners' capital $ 29,716 (1) Consists of $15.0 million of cash plus 4.5 million new common units at an issue price of $13.92 , the closing price of the Partnership’s common units on May 7, 2015. Supplemental Disclosures - As If Pooled Basis. As noted above, the 2015 Holdings Acquisition was between commonly controlled entities which required that we account for the acquisitions in a manner similar to a pooling of interests. As a result, the historical financial statements of the Partnership and the Valley Wells System and Compression Assets have been combined to reflect the historical operations, financial position and cash flows from the date common control began on August 4, 2014. Revenues and net income for the previously separate entities and the combined amounts for the year ended December 31, 2015, are as follows (in thousands): Year Ended December 31, 2015 Partnership revenues $ 691,424 Valley Wells System and Compression Assets revenue 7,049 Combined revenues $ 698,473 Partnership net loss $ (51,235 ) Valley Wells System and Compression Assets net loss (4,258 ) Combined net loss $ (55,493 )

EARNINGS PER LIMITED PARTNER UN

EARNINGS PER LIMITED PARTNER UNIT AND DISTRIBUTIONS	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
EARNINGS PER LIMITED PARTNER UNIT AND DISTRIBUTIONS	PER LIMITED PARTNER UNIT AND DISTRIBUTIONS Net Loss Per Limited Partner Unit The following is a reconciliation of net loss attributable to limited partners and the limited partner units used in the basic and diluted earnings per unit calculations for the years ended December 31, 2016 and 2015 (in thousands, except unit and per unit data): Year Ended December 31, 2016 2015 (1) Net loss $ (94,948 ) $ (55,493 ) General partner unit in-kind distribution (47 ) (164 ) Net loss attributable to Holdings — (4,258 ) Net loss attributable to partners $ (94,995 ) $ (51,399 ) General partner's interest (1) $ (1,911 ) $ (1,084 ) Class B Convertible limited partner interest (1) (24,383 ) (14,225 ) Limited partners' interest (1) Common $ (50,612 ) $ (24,790 ) Subordinated (18,089 ) (11,300 ) _____________________________________________________________ (1) General Partner's and limited partners’ interests are calculated based on the allocation of net losses for the period, net of the General Partner unit in-kind distributions. The Class B Convertible Unit ("Class B Convertible Units") interest is calculated based on the allocation of only net losses for the period. Year Ended December 31, Common Units 2016 2015 Interest in net loss $ (50,612 ) $ (24,790 ) Effect of dilutive units - numerator (1) — — Dilutive interest in net loss $ (50,612 ) $ (24,790 ) Weighted-average units - basic 34,160,860 26,780,825 Effect of dilutive units - denominator(1) — — Weighted-average units - dilutive 34,160,860 26,780,825 Basic and diluted net loss per common unit $ (1.48 ) $ (0.93 ) Year Ended December 31, Subordinated Units 2016 2015 Interest in net loss $ (18,089 ) $ (11,300 ) Effect of dilutive units - numerator (1) — — Dilutive interest in net loss $ (18,089 ) $ (11,300 ) Weighted-average units - basic 12,213,713 12,213,713 Effect of dilutive units - denominator (1) — — Weighted-average units - dilutive 12,213,713 12,213,713 Basic and diluted net loss per subordinated unit $ (1.48 ) $ (0.93 ) ____________________________________________________________________________ (1) Because we had a net loss for all periods for common units and the subordinated units, the effect of the dilutive units would be anti-dilutive to the per unit calculation. Therefore, the weighted average units outstanding are the same for basic and dilutive net loss per unit for those periods. The weighted average units that were not included in the computation of diluted per unit amounts were 19,453 and 17,168 and unvested awards granted under our LTIP for the years ended December 31, 2016 and 2015, respectively. Our calculation of the number of weighted-average units outstanding includes the common units that have been awarded to our directors that are deferred under our Non-Employee Director Deferred Compensation Plan. Distributions Cash Distributions The board of directors of our General Partner suspended paying a quarterly distribution with respect to the fourth quarter of 2015 and every quarter of 2016 to reserve any excess cash for the operation of our business. The board of directors of our General Partner and our management believe this suspension to be in the best interest of our unitholders and will continue to evaluate our ability to reinstate the distribution in future periods. Additionally, we are restricted under the fifth amendment to the Third A&R Revolving Credit Agreement from paying a distribution until our Consolidated Total Leverage Ratio is below 5.0. Our agreement of limited partnership (as amended and restated, the “Partnership Agreement”), requires that within 45 days after the end of each quarter, we distribute all of our available cash to unitholders of record on the applicable record date, as determined by our General Partner. There is no guarantee that we will pay the minimum quarterly distribution on our units in any quarter. Beginning with the third quarter of 2014, until such time that we have a distributable cash flow divided by cash distributions ratio (“Distributable Cash Flow Ratio”) of at least 1.0 , Holdings, the indirect holder of all of our subordinated units, waived the right to receive distributions on any subordinated units that would cause the Distributable Cash Flow Ratio to be less than 1.0 . In addition, the First Amendment (as defined in Note 7) imposed additional restrictions on our ability to declare and pay quarterly cash distributions with respect to our subordinated units. See Note 7. Holdings did not receive a distribution for the first quarter of 2015 in respect of the 4.5 million common units acquired by it in connection with the 2015 Holdings Acquisition. The following table represents our distributions paid for previous periods (in thousands, except per unit data): Distributions Attributable to the Per Unit Limited Partners Payment Date Quarter Ended Distribution Common Subordinated General Partner Total 2015 November 13, 2015 September 30, 2015 $ 0.40 $ 11,368 $ — $ 459 $ 11,827 August 14, 2015 June 30, 2015 0.40 11,325 — 457 11,782 May 14, 2015 March 31, 2015 0.40 9,520 — 418 9,938 Paid In-Kind Distributions Class B Convertible Units. As of December 31, 2016, the Class B Convertible Units consisted of 17,105,875 of such units including the additional Class B Convertible Units issued in-kind as a distribution (“Class B PIK Units”). The Class B Convertible Units are not participating securities for purposes of the earnings per unit calculation. Commencing with the quarter ended September 30, 2014 and until converted, as long as certain requirements are met, the holders of the Class B Convertible Units will receive quarterly distributions in an amount equal to $0.3257 per unit. These distributions will be paid quarterly in Class B PIK Units within 45 days after the end of each quarter. Our General Partner was entitled, and has exercised its right, to retain its 2.0% general partner interest in us in connection with the original issuance of Class B Convertible Units. In connection with future distributions of Class B PIK Units, the General Partner is entitled to a corresponding distribution to maintain its 2.0% general partner interest in us. The Class B Convertible Units have the same rights, preferences and privileges, and are subject to the same duties and obligations, as our common units, with certain exceptions. See Note 10. The following table represents the PIK distribution paid on the Class B Convertible Units for periods ended December 31, 2015 and December 31, 2016 (in thousands, except per unit and in-kind distribution units): Payment Date Attributable to the Quarter Ended Per Unit Distribution In-Kind Class B Convertible Unit In-Kind Class B Convertible Distributions (1) In-Kind Unit to General Partner In-Kind General Partner Distribution Value (1) 2016 February 14, 2017 December 31, 2016 $ 0.3257 299,375 $ 404 6,109 $ 8 November 24, 2016 September 30, 2016 0.3257 294,226 433 6,004 9 August 10, 2016 June 30, 2016 0.3257 289,165 581 5,901 12 May 9, 2016 (2) 0.3257 563,494 1,293 11,499 26 2015 November 13, 2015 September 30, 2015 $ 0.3257 274,478 $ 1,353 5,601 $ 28 August 14, 2015 June 30, 2015 0.3257 269,758 2,994 5,505 61 May 14, 2015 March 31, 2015 0.3257 265,118 3,712 5,410 76 (1) The fair value was calculated as required, based on the common unit price at the quarter end date for the period attributable to the distribution, multiplied by the number of units distributed. (2) We suspended distributions to holders of our Class B Convertible Units for the quarters ended December 31, 2015 and March 31, 2016. However, under the terms of our Partnership agreement, such paid in-kind (“PIK”) distributions continued to accumulate. On May 9, 2016, we issued the accumulated Class B Convertible Units to Holdings and general partner units to our General Partner related to the quarters ended December 31, 2015 and March 31, 2016.

Transaction-Related Costs

Transaction-Related Costs	12 Months Ended
	Dec. 31, 2015
Business Combinations [Abstract]
Transaction-Related Costs	ACQUISITIONS Holdings Drop-Down Acquisition. On May 7, 2015, we completed the acquisition of gathering, treating, compression and transportation assets (the “2015 Holdings Acquisition”) consisting of the Valley Wells sour gas gathering and treating system (the "Valley Wells System"), compression assets that are part of the Valley Wells and Lancaster gathering and treating systems (the "Compression Assets") and two NGL pipelines pursuant to a Purchase, Sale and Contribution Agreement among Holdings, TexStar Midstream Utility, LP, Frio LaSalle Pipeline, LP (“Frio”), us and certain of our subsidiaries. Total consideration for the assets was $77.6 million , consisting of $15.0 million in cash and 4.5 million new common units, valued as of the date of closing and issued to Holdings. We also assumed the remaining capital expenditures for the completion of the NGL pipelines that were under construction. The 2015 Holdings Acquisition was deemed a transaction between entities under common control and, as such, was accounted for on an “as if pooled” basis for all periods which common control existed (which began on August 4, 2014). The Partnership’s financial results retrospectively include the financial results of the Valley Wells System and Compression Assets for all periods ending after August 4, 2014 and before May 7, 2015. The acquired NGL pipelines were accounted for as an asset acquisition and were included in the historical financial statements beginning on May 7, 2015. The amount of consideration paid below Holdings' net book value of the assets received and liabilities assumed of the 2015 Holdings Acquisition was recorded as an increase to partners' capital as summarized as follows (in thousands): Consideration paid (1) $ 77,640 Total net assets contributed 107,356 Net assets contributed in excess of consideration paid $ 29,716 Allocation of increase to partners' capital: Common limited partner interest $ 14,806 Class B Convertible limited partner interest 7,929 Subordinated limited partner interest 6,387 General Partner interest 594 Total increase to partners' capital $ 29,716 (1) Consists of $15.0 million of cash plus 4.5 million new common units at an issue price of $13.92 , the closing price of the Partnership’s common units on May 7, 2015. Supplemental Disclosures - As If Pooled Basis. As noted above, the 2015 Holdings Acquisition was between commonly controlled entities which required that we account for the acquisitions in a manner similar to a pooling of interests. As a result, the historical financial statements of the Partnership and the Valley Wells System and Compression Assets have been combined to reflect the historical operations, financial position and cash flows from the date common control began on August 4, 2014. Revenues and net income for the previously separate entities and the combined amounts for the year ended December 31, 2015, are as follows (in thousands): Year Ended December 31, 2015 Partnership revenues $ 691,424 Valley Wells System and Compression Assets revenue 7,049 Combined revenues $ 698,473 Partnership net loss $ (51,235 ) Valley Wells System and Compression Assets net loss (4,258 ) Combined net loss $ (55,493 )

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2016
Investments, All Other Investments [Abstract]
FINANCIAL INSTRUMENTS	INANCIAL INSTRUMENTS Fair Value Measurements We apply recurring fair value measurements to our financial assets and liabilities. In estimating fair value, we generally use a market approach and incorporate assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and/or the risks inherent in the inputs to the valuation techniques. The fair value measurement inputs we use vary from readily observable inputs that represent market data obtained from independent sources to unobservable inputs that reflect our own market assumptions that cannot be validated through external pricing sources. Based on the observability of the inputs used in the valuation techniques, the financial assets and liabilities carried at fair value in the financial statements are classified as follows: • Level 1—Represents unadjusted quoted market prices in active markets for identical assets or liabilities that are accessible at the measurement date. This category primarily includes our cash and cash equivalents. • Level 2—Represents quoted market prices for similar assets or liabilities in active markets, quoted market prices in markets that are not active or other inputs that are observable or can be corroborated by observable market data. This category primarily includes variable rate debt, over-the-counter swap contracts based upon natural gas price indices and interest rate derivative transactions. • Level 3—Represents derivative instruments whose fair value is estimated based on internally developed models and methodologies utilizing significant inputs that are generally less readily observable from market sources. We do not have financial assets and liabilities classified as Level 3. In certain cases, the inputs used to measure fair value may fall into different levels of the fair value hierarchy. In such cases, the level in the fair value hierarchy must be determined based on the lowest level input that is significant to the fair value measurement. An assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and consideration of factors specific to the asset or liability. The carrying amounts of cash and cash equivalents, accounts receivable and accounts payable represent fair values based on the short-term nature of these instruments. The fair value of our Credit Facility (defined in Note 7) approximates its carrying amount due primarily to the variable nature of the interest rate of the instrument and is considered a Level 2 fair value measurement. As of December 31, 2016, the fair value of our term loan was $350.0 million , based on recent trading levels and is considered a Level 2 fair value instrument. Derivative Financial Instruments Interest Rate Derivative Transactions We enter into interest rate swap contracts whereby we receive a floating rate and pay a fixed rate to reduce the risk associated with the variability of interest rates for our term loan borrowings. Our interest rate swap position was as follows (in thousands): Estimated Fair Value Notional Amount Fixed Rate Effective Date Maturity Date December 31, 2016 100,000 1.195 % June 30, 2015 January 1, 2017 (15 ) Effectively, we enter into interest rate cap contracts to limit our London Interbank Offered Rate ("LIBOR")-based interest rate risk on the portion of debt hedged at the contracted cap rate. Our interest rate cap position was as follows (in thousands): Estimated Fair Value Notional Amount Cap Rate Effective Date Maturity Date December 31, 2016 $ 20,000 1.500 % December 31, 2014 December 31, 2016 — 80,000 3.000 % June 30, 2015 June 30, 2017 — 50,000 3.000 % December 31, 2015 December 31, 2017 — 50,000 3.000 % June 30, 2016 June 30, 2018 4 40,000 3.000 % December 31, 2016 January 1, 2018 — 40,000 3.000 % December 31, 2016 July 1, 2018 3 40,000 3.000 % December 31, 2016 January 1, 2019 14 $ 21 In December 2016, we entered into three new interest rate cap contracts for $40.0 million notional values, each effective December 31, 2016. The new interest rate cap contracts provide for maturity dates of January 1, 2018, July 1, 2018 and January 1, 2019. The contracts effectively cap our LIBOR-based interest rate on the portion of debt at 3.0% . These interest rate derivatives are not designated as cash flow hedging instruments for accounting purposes and as a result, changes in the fair value are recognized in interest expense immediately. The fair value of our interest rate derivative transactions is determined based on a discounted cash flow method using contractual terms of the transactions. The floating coupon rate is based on observable rates consistent with the frequency of the interest cash flows. We have elected to present our interest rate derivatives net on the balance sheets. There was no effect of offsetting on the balance sheets as of December 31, 2016 and 2015. The fair values of our interest rate derivative transactions were as follows (in thousands): Significant Other Observable Inputs (Level 2) Fair Value Measurement as of December 31, 2016 December 31, 2015 Current interest rate derivative assets $ 2 $ 6 Non-current interest rate derivative assets 2 4 Current interest rate derivative (liabilities) (15 ) (169 ) Total interest rate derivatives $ (11 ) $ (159 ) The realized and unrealized amounts recognized in interest expense associated with derivatives were as follows (in thousands): Year Ended December 31, 2016 2015 Unrealized gain on interest rate derivatives $ (147 ) $ (1 ) Realized loss on interest rate derivatives 283 416 Commodity Swaps In our normal course of business, we periodically enter into month-ahead swap contracts to hedge our exposure to certain intra-month natural gas index pricing risk. We define these contracts as Level 2 because the index price associated with such contracts is observable and tied to a similarly quoted first-of-the-month natural gas index price. We have elected to present our commodity swaps net on the balance sheets, however there are no offsetting liabilities for the periods presented. We had no outstanding commodity swaps at December 31, 2016 and December 31, 2015 . We did not have any cash collateral received or paid on our commodity swaps as of December 31, 2016 and 2015 . The realized and unrealized gain/loss on these derivatives, recognized in revenues in our statements of operations, were as follows (in thousands): Year ended December 31, 2016 2015 Realized gain on commodity swap derivatives $ — $ 214 Unrealized loss on commodity swap derivatives — (111 )

LONG-LIVED ASSETS

LONG-LIVED ASSETS	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
LONG-LIVED ASSETS	LONG-LIVED ASSETS Property, Plant and Equipment Property, plant and equipment consist of the following (in thousands): Estimated Useful Life As of December 31, 2016 2015 Pipelines 15-30 $ 552,540 $ 542,790 Gas processing, treating and other plants 15 509,840 547,253 Compressors 5-15 72,054 72,750 Rights of way and easements 15 49,998 46,692 Furniture, fixtures and equipment 5 9,269 9,252 Capital lease vehicles 3-5 1,713 2,442 Total property, plant and equipment 1,195,414 1,221,179 Accumulated depreciation and amortization (262,709 ) (212,991 ) Total 932,705 1,008,188 Construction in progress 16,150 32,214 Land and other 22,431 25,599 Property, plant and equipment, net $ 971,286 $ 1,066,001 Depreciation is provided using the straight-line method based on the estimated useful life of each asset. Depreciation expense for the year ended December 31, 2016 included $32.5 million (the earnings per unit equivalent of $0.51 for the year ended December 31, 2016) of accelerated depreciation resulting from the assets' shortened useful life due to shutting down the Conroe facility and converting the Gregory facility to a compressor station in 2016. Depreciation expense for the year ended December 31, 2016 and 2015, was $106.9 million and $70.8 million , respectively. We notified our producers that the Conroe plant would be idled by December 31, 2016. On August 4, 2016, the Gregory plant was idled while work commenced to convert the Gregory plant into a compressor station. The assets at the Gregory plant that will not be used as part of the compressor station will be sold or scrapped. The gas previously processed at the Gregory plant was re-rerouted to our Woodsboro facility during 2016 where we expect such gas to be processed going forward. In May 2016, we finalized the sale of a portion of pipeline for $15.0 million , which was determined to be a sale of assets. We recorded a $13.6 million gain on sale of assets on our consolidated statement of operations in connection with this sale. In January 2015, we shut down our Gregory facility for four weeks due to a fire at the facility. In December 2016, we reached a settlement related to the Gregory processing plant fire with our insurance carriers. We received the payment of $2.0 million from our insurance carriers in the first quarter of 2017 and used a portion of the proceeds to pay down on our term loan. Intangible Assets Intangible assets of $1.4 million and $1.5 million as of December 31, 2016 and 2015 , respectively, represent the unamortized value assigned to long-term supply and gathering contracts acquired in 2011. These intangible assets are amortized on a straight-line basis over the 30 -year expected useful lives of the contracts through 2041. Amortization expense over the next five years related to intangible assets is not significant.

LONG-TERM DEBT

LONG-TERM DEBT	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT Our outstanding debt and related information at December 31, 2016 and 2015 is as follows (in thousands): As of December 31, 2016 2015 Revolving credit facility due 2019 $ 122,555 $ 181,695 Term loans (including original issue discount of $1.5 million and $1.8 million as of December 31, 2016 and 2015, respectively) due 2021 437,291 441,464 Total long-term debt (including current portion) 559,846 623,159 Current portion of long-term debt (4,500 ) (4,500 ) Debt issuance costs (11,474 ) (14,141 ) Total long-term debt $ 543,872 $ 604,518 Outstanding letters of credit $ 19,378 $ 18,305 Remaining unused borrowings $ 3,067 $ — Year Ended December 31, 2016 2015 Weighted average interest rate 5.25 % 5.16 % Average outstanding borrowings $ 591,970 $ 564,568 Maximum borrowings $ 628,055 $ 624,945 Total 2017 2018 2019 2020 Thereafter Maturity Long-term debt $ 561,305 $ 4,500 $ 4,500 $ 127,055 $ 4,500 $ 420,750 Senior Credit Facilities Our long-term debt arrangements consist of (i) the Third A&R Revolving Credit Agreement (as defined in Note 2) and (ii) a Term Loan Credit Agreement with Wilmington Trust, National Association, UBS Securities LLC and Barclays Bank PLC and a syndicate of lenders (the “Term Loan Agreement” and, together with the Third A&R Revolving Credit Agreement, the “Senior Credit Facilities”). Substantially all of our assets are pledged as collateral under the Senior Credit Facilities, with the security interest of the facilities ranking pari passu. Third A&R Revolving Credit Agreement The Third A&R Revolving Credit Agreement is a five -year $200 million revolving credit facility due August 4, 2019 (the “Credit Facility”). Borrowings under our Credit Facility bear interest at the LIBOR plus an applicable margin or a base rate as defined in the respective credit agreement. Pursuant to the Third A&R Revolving Credit Agreement, among other things: (a) the letters of credit sublimit was set at $75.0 million ; (b) if we fail to comply with the consolidated total leverage ratio, consolidated senior secured leverage raio and the consolidate interest coverage ratio covenants (the "Financial Covenants") (a “Financial Covenant Default”), we have the right (a limited number times) to cure such Financial Covenant Default by having the Sponsors purchase equity interests in or make capital contributions to us resulting in, among other things, proceeds that, if added to consolidated EBITDA, as defined in the Third A&R Revolving Credit Agreement, would result in us satisfying the Financial Covenants Amendments to Third A&R Revolving Credit Agreement On May 7, 2015, we entered into the first amendment to our Third A&R Revolving Credit Agreement among the Partnership, as the borrower, the lenders and other parties thereto (the “First Amendment”). The First Amendment, among other things: (i) (a) revised the maximum consolidated total leverage ratio set at 5.25 to 1.0 as of the last day of the fiscal quarter ending September 30, 2016, and (b) 5.00 to 1.0 as of the last day of each fiscal quarter thereafter, in each case, without any step-ups in connection with acquisitions; (ii) increased the applicable margins used in connection with the loans and the commitment fee so that the applicable margin for Eurodollar Loans (as used in the Third A&R Revolving Credit Agreement) ranges from 2.00% to 4.50% , the applicable margin for base rate loans ranges from 1.00% to 3.50% and the applicable rate for commitment fees ranges from 0.375% to 0.500% ; (iii) allowed us an unlimited number of quarterly equity cures related to our Financial Covenant Default through the fourth quarter of 2016, and no more than two in a twelve month period thereafter for the life of the agreement. Beginning on January 1, 2017, we are limited to no more than four equity cures, with no more than two in a twelve month period. Additionally, we were unable to borrow on our Credit Facility until we have funded the required equity cure for the third quarter of 2016; however, we retained the ability to execute the required equity cure. On July 25, 2016, we determined Holdings’ cash contribution to us for the first quarter 2016 equity cure had not been transferred to us timely, as required under the Third A&R Revolving Credit Agreement, due to an administrative oversight, which resulted in a default. On July 26, 2016, Holdings fully funded the first quarter 2016 equity cure. On August 4, 2016, we entered into the limited waiver and second amendment to the Third A&R Revolving Credit Agreement whereby the lenders waived any default or right to exercise any remedy as a result of this technical event of default to fund timely the first quarter 2016 equity cure. On November 8, 2016, we entered into the Third Amendment which stipulated, among other things, that i) the equity cure funding deadline for the quarter ended September 30, 2016 (“Q3 2016 Equity Cure”) was extended from November 23, 2016 to December 16, 2016, and ii) the total revolving credit exposure (generally defined as funded borrowings plus letters of credit issued and outstanding) was limited to $145.2 million until the Q3 2016 Equity Cure was funded. The Third Amendment stipulated, among other things, that any Excess Cash Balance (generally defined as unrestricted book cash on hand that exceeds $15 million ) as of the last business day of each week would be used to temporarily reduce funded borrowings under our revolving credit facility. On December 9, 2016, we entered into the Fourth Amendment which stipulated, among other things, that i) the deadline for funding the Q3 2016 Equity Cure was further extended from December 16, 2016 to January 12, 2017, and ii) the Third A&R Revolving Credit Agreement was amended to require that any account into which we deposited funds, securities or commodities be subject to a lien and control agreement for the benefit of the secured parties under the Third A&R Revolving Credit Agreement. On December 29, 2016, we entered into the Fifth Amendment which, among other things: (i) permits a full waiver for all defaults or events of default arising out of our failure to comply with the financial covenant to maintain a Consolidated Total Leverage Ratio less than 5.00 to 1.00 for the quarter ended September 30, 2016; (ii) reduced the total aggregate commitments under the Third A&R Revolving Credit Agreement from $200 million to $145 million and reduced the sublimit for letters of credit from $75 million to $50 million . Total aggregate commitments will be further reduced to $140 million on September 30, 2017, $135 million on December 31, 2017, $125 million on March 31, 2018, $120 million on June 30, 2018 and $115 million on December 31, 2018 and will also be reduced in an amount equal to the net proceeds of any Permitted Note Indebtedness we may incur in the future; (iii) modified the borrowings under the Third A&R Revolving Credit Agreement to bear interest at the LIBOR or a base rate plus an applicable margin that cumulatively increases pursuant to the Amendment by (a) 125 basis points if our Consolidated Total Leverage Ratio is greater than or equal to 5.00 to 1.00 , plus (b) 100 basis points if our Consolidated Total Leverage Ratio is greater than or equal to 6.00 to 1.00 , plus (c) 100 basis points if our Consolidated Total Leverage Ratio is greater than or equal to 7.00 to 1.00 , plus (d) 100 basis points if our Consolidated Total Leverage Ratio is greater than or equal to 8.00 to 1.00 . At our election, the 100 basis point increase to the Applicable Margin upon our Consolidated Total Leverage Ratio being greater than or equal to 8.00 to 1.00 may be replaced with a 150 basis point increase that is payable in kind; (iv) suspends the Consolidated Total Leverage Ratio and Consolidated Senior Secured Leverage Ratio financial covenants and reduces the Consolidated Interest Coverage Ratio financial covenant requirement from 2.50 to 1.00 to 1.50 to 1.00 for all periods ending on or prior to the Ratio Compliance Date; (v) requires us to generate Consolidated EBITDA in certain minimum amounts beginning with the quarter ending December 31, 2016 and rolling forward thereafter through the quarter ending December 31, 2018; (vi) requires us to maintain at least $3 million of Liquidity as of the last business day of each calendar week; (vii) restricts our capital expenditures for growth and maintenance to not exceed certain amounts per fiscal year; and (viii) beginning with the fiscal quarter ending March 31, 2019, our Consolidated Total Leverage Ratio cannot exceed 5.00 to 1.00 and our Consolidated Senior Secured Leverage Ratio cannot exceed 3.50 to 1.00 . Until such time as our Consolidated Total Leverage Ratio is less than 5.00 to 1.00 , we will also be restricted from making cash distributions to our unitholders and from entering into acquisition or merger agreements with third-party businesses involving a purchase price greater than $10 million , unless such acquisition is funded entirely using the proceeds from the issuance of equity. In addition, until such time as our Consolidated Total Leverage Ratio is less than or equal to 5.00 to 1.00 , we will be required to repay any outstanding borrowings under the Third A&R Revolving Credit Agreement in an amount equal to 50% of our Excess Cash Flow. On January 7, 2016, in response to our need for additional liquidity, we issued at par Senior Unsecured PIK Notes in the aggregate principal amount of $14 million (the "PIK Notes") to affiliates of EIG and Tailwater, with interest at a rate of 7% due January 7, 2017. Contemporaneous with the resolution of Holdings’ bankruptcy proceedings in April 2016, the PIK Notes and the related PIK interest of $0.3 million were repaid in full. Term Loan Agreement The Term Loan Agreement is a seven-year $450 million senior secured term loan facility maturing on August 4, 2021. Borrowings under our Term Loan Agreement bear interest at LIBOR plus 4.25% or a base rate as defined in the respective credit agreement with a LIBOR floor of 1.00% . The facility is amortized in equal quarterly installments in an aggregate annual amount equal to 1% of the original principal amount of the initial loan ( $1.125 million ), with the remainder due on the maturity date.

COMMITMENTS AND CONTINGENT LIAB

COMMITMENTS AND CONTINGENT LIABILITIES	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENT LIABILITIES	COMMITMENTS AND CONTINGENT LIABILITIES Legal Matters From time to time, we are party to certain legal or administrative proceedings that arise in the ordinary course and are incidental to our business. For example, during periods when we are expanding our operations through the development of new pipelines or the construction of new plants, we may become involved in disputes with landowners that are in close proximity to our activities. While we currently are involved in several such proceedings and disputes, our management believes that none of such proceedings or disputes will have a material adverse effect on our results of operations, cash flows or financial condition. However, future events or circumstances, currently unknown to management, will determine whether the resolution of any litigation or claims ultimately will have a material effect on our results of operations, cash flows or financial condition in any future reporting periods. Formosa. On March 5, 2013, one of our subsidiaries, Southcross Marketing Company Ltd., filed suit in a District Court of Dallas County against Formosa Hydrocarbons Company, Inc. (“Formosa”). The lawsuit sought recoveries of losses that we believe our subsidiary experienced as a result of the failure of Formosa to perform certain obligations under the gas processing and sales contract between the parties. Formosa filed a response generally denying our claims and, later, Formosa filed a counterclaim against our subsidiary claiming our subsidiary breached the gas processing and sales contract and a related agreement between the parties for the supply by Formosa of residue gas to a third party on behalf of our subsidiary. On December 30, 2016, we reached a final settlement with Formosa and the appeals have been dismissed. We were awarded $3.1 million , of which we received $1.6 million on December 30, 2016. We recorded a receivable of $1.6 million in our consolidated balance sheets as of December 31, 2016 for the remaining balance, which was received in January 2017. Regulatory Compliance In the ordinary course of our business, we are subject to various laws and regulations. In the opinion of our management, compliance with current laws and regulations will not have a material effect on our results of operations, cash flows or financial condition. Leases Capital Leases We have auto leases classified as capital leases. The termination dates of the lease agreements vary from 2017 to 2019. We recorded amortization expense related to the capital leases of $0.4 million and $0.5 million for the years ended December 31, 2016 and 2015 , respectively. Capital leases entered into during the years ended December 31, 2016 and 2015 were each $0.4 million . The capital lease obligation amounts included on the balance sheets were as follows (in thousands): December 31, 2016 December 31, 2015 Other current liabilities $ 396 $ 362 Other non-current liabilities 497 522 Total $ 893 $ 884 Operating Leases We maintain operating leases in the ordinary course of our business activities. These leases include those for office and other operating facilities and equipment. The termination dates of the lease agreements vary from 2017 to 2025. Expenses associated with operating leases, recorded in operations and maintenance expenses and general and administrative expenses in our statements of operations, were $5.8 million and $5.3 million for the years ended December 31, 2016 and 2015 , respectively. A rental reimbursement included in our lease agreement associated with the office space we leased in June 2015 of $2.3 million was recorded as a deferred liability on our consolidated balance sheets as of December 31, 2016. This amount will be amortized against the lease payments over the length of the lease term. Future Minimum Lease Payments Future minimum annual rental commitments under our capital and operating leases at December 31, 2016 were as follows (in thousands): Years Ending December 31, Capital Leases Operating Leases 2017 $ 396 $ 3,634 2018 291 3,477 2019 145 3,409 2020 61 2,912 2021 — 1,148 Thereafter — 4,912 Total future payments 893 $ 19,492 Less: Imputed interest $ — Future lease payments $ 893

TRANSACTIONS WITH RELATED PARTI

TRANSACTIONS WITH RELATED PARTIES	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
TRANSACTIONS WITH RELATED PARTIES	TRANSACTIONS WITH RELATED PARTIES Affiliated Directors The board of directors of our General Partner is comprised of two directors designated by EIG (one of which must be independent), two directors designated by Tailwater (one of which must be independent), two directors designated by the Lenders (one of which must be independent) and one director by majority. Our non-employee directors are reimbursed for certain expenses incurred for their services to us. The director services fees and expenses are included in general and administrative expenses in our statements of operations. We incurred fees and expenses related to the services from our affiliated directors as follows (in thousands): Year Ended December 31, 2016 2015 Charlesbank Capital Partners, LLC (1) $ 97 $ 148 EIG 62 64 Tailwater 61 64 Total fees and expenses paid for director services to affiliated entities $ 220 $ 276 (1) Charlesbank Capital Partners, LLC indirectly owned approximately one-third of Holdings until April 13, 2016. See Note 1. Southcross Energy Partners GP, LLC (our General Partner) Our General Partner does not receive a management fee or other compensation for its management of us. However, our General Partner and its affiliates are entitled to reimbursements for all expenses incurred on our behalf, including, among other items, compensation expense for all their employees required to manage and operate our business. We incurred expenses related to these reimbursements as follows (in thousands): Year Ended December 31, 2016 2015 Reimbursements included in general and administrative expenses $ 11,894 $ 15,790 Reimbursements included in operations and maintenance expenses 20,872 20,045 Total reimbursements to our General Partner and its affiliates $ 32,766 $ 35,835 Compensation expense for services incurred by us on behalf of Southcross Energy LLC was billed to Southcross Energy LLC. Compensation expense not incurred on our behalf of $0.6 million for the year ended December 31, 2015 was billed to Southcross Energy LLC. Other Transactions with Affiliates On March 17, 2016, our General Partner entered into retention agreements with certain executives of our General Partner, pursuant to which the executives received a one-time special restructuring bonus in an amount equal to 100% of then-current annual salary for remaining employed with our General Partner through the date of Holdings’ emergence from bankruptcy. The bonuses of $1.5 million were paid by Holdings on April 22, 2016. In addition, on November 3, 2016, each of these executives of our General Partner received a one-time retention bonus in an amount equal to 100% of then-current annual salary for remaining employed with our General Partner through November 1, 2016. The bonuses of $1.5 million were paid by Holdings. On January 7, 2016, in response to our need for additional liquidity, we issued the PIK Notes to affiliates of EIG and Tailwater, with interest at a rate of 7% due January 7, 2017. Contemporaneous with the resolution of Holdings’ bankruptcy proceedings in April 2016, the PIK Notes and the related PIK interest of $0.3 million were repaid in full. We have a gas gathering and processing agreement (the “G&P Agreement”) and an NGL sales agreement (the “NGL Agreement”) with an affiliate of Holdings. Under the terms of these commercial agreements, we transport, process and sell rich natural gas for the affiliate of Holdings in return for agreed-upon fixed fees, and we can sell natural gas liquids that we own to Holdings at agreed-upon fixed prices. The NGL Agreement also permits us to utilize Holdings’ fractionation services at market-based rates. We had purchases of NGLs from Holdings of $10.0 million for the year ended December 31, 2016. We have a series of commercial agreements with affiliates of Holdings including a gas gathering and treating agreement, a compression services agreement, a repair and maintenance agreement and an NGL transportation agreement. Under the terms of these commercial agreements, we gather, treat, transport, compress and redeliver natural gas for the affiliates of Holdings in return for agreed-upon fixed fees. In addition, under the NGL transportation agreement, we transport a minimum volume of NGLs per day at a fixed rate per gallon. The operational expense associated with such agreements was capped at $1.7 million per quarter through December 31, 2016. In the first and second quarters of 2016, we exceeded this cap by $1.0 million and $1.4 million , respectively. We did not exceed this cap in the third or fourth quarter of 2016. We recorded revenues from affiliates of $97.5 million and $94.7 million for the years ended December 31, 2016 and 2015 , respectively, in accordance with the G&P Agreement, the NGL Agreement and the series of commercial agreements. We had accounts receivable due from affiliates of $8.0 million and $49.7 million as of December 31, 2016 and 2015 , respectively, and accounts payable due to affiliates of $0.5 million and $7.9 million as of December 31, 2016 and 2015 , respectively. The affiliate receivable and payable balances are related primarily to transactions associated with Holdings, noted above, and our joint venture investments (defined in Note 13). The receivable balance due from Holdings is current as of December 31, 2016. During the year ended December 31, 2015, Holdings purchased $2.3 million of office leasehold improvements from us. See Note 10 for our issuance of common units to Holdings. In connection with the execution of the Fifth Amendment, on December 29, 2016, the Partnership entered into (i) the Investment Agreement with Holdings and Wells Fargo Bank, N.A., (ii) the Backstop Agreement with Holdings, Wells Fargo Bank, N.A. and the Sponsors and (iii) the Equity Cure Contribution Amendment with Holdings. See Notes 2 and 7 for additional details.

SERIES A CONVERTIBLE PREFERRED

SERIES A CONVERTIBLE PREFERRED UNITS SERIES A CONVERTIBLE PREFERRED UNITS	12 Months Ended
	Dec. 31, 2016
Statement of Partners' Capital [Abstract]
SERIES A CONVERTIBLE PREFERRED UNITS	PARTNERS' CAPITAL Ownership Our units outstanding as of December 31, 2016 are as follows (in units): Partners’ Capital Owned By Parent Public Holdings Class B General Common Common Convertible Subordinated Partner Units outstanding as of December 31, 2014 21,684,543 2,116,400 14,889,078 12,213,713 1,038,852 Common unit issuance related to the Holdings Acquisition — 4,500,000 — — — Board of Director grants 17,185 — — — — Vesting of LTIP units, net 102,491 — — — — In-kind distributions and general partner issuances to maintain 2.0% ownership — — 1,069,912 — 116,113 Units outstanding as of December 31, 2015 21,804,219 6,616,400 15,958,990 12,213,713 1,154,965 Vesting of LTIP units, net 205,797 — — — — In-kind distributions and issuances to general partner to maintain 2.0% ownership — — 1,146,885 — 433,233 Common unit issuances to Holdings related to equity cures — 19,875,674 — — — Units outstanding as of December 31, 2016 22,010,016 26,492,074 17,105,875 12,213,713 1,588,198 Common units Our common units represent limited partner interests in us. The holders of our common units are entitled to participate in our distributions (to the extent distributions are made) and are entitled to exercise the rights and privileges available to limited partners under our Partnership Agreement. In accordance with the requirements of the Equity Cure Agreement, Holdings was issued 8,029,729 common units on May 2, 2016 for the fourth quarter 2015 equity cure of $11.9 million and 359,459 common units on May 13, 2016 for the first quarter 2016 equity cure of $0.5 million . Pursuant to the Equity Cure Contribution Amendment, Holdings contributed $17.0 million to the Partnership in exchange for 11,486,486 common units on December 29, 2016. The proceeds of the $17.0 million contribution were used to pay down the outstanding balance under the Third A&R Revolving Credit Agreement and for general corporate purposes. On May 7, 2015, we completed the 2015 Holdings Acquisition for total consideration of $77.6 million , consisting of $15.0 million in cash and 4.5 million new common units, valued as of the date of closing and issued to Holdings. Class B Convertible Units As of December 31, 2016, the Class B Convertible Units consist of 17,105,875 units, inclusive of any Class B paid in-kind (“PIK”) Units issued. The Class B Convertible Units have the same rights, preferences and privileges, and are subject to the same duties and obligations, as our common units, with certain exceptions as noted below. Our Partnership Agreement does not allow additional Class B Convertible Units (other than Class B PIK Units) to be issued without the prior approval of our General Partner and the holders of a majority of the outstanding Class B Convertible Units. As of December 31, 2016, all of our outstanding Class B Convertible Units were indirectly owned by Holdings. Distribution Rights: The holders of the Class B Convertible Units will receive quarterly distributions in an amount equal to $0.3257 per unit paid in Class B PIK Units (based on a unit issuance price of $18.61 ) within 45 days after the end of each quarter. Our General Partner was entitled, and has exercised its right, to retain its 2.0% general partner interest in us in connection with the original issuance of Class B Convertible Units. In connection with future distributions of Class B PIK Units, the General Partner is entitled to a corresponding distribution to maintain its 2.0% general partner interest in us. We suspended distributions to holders of our Class B Convertible Units for the quarter ended December 31, 2015. However, under the terms of our Partnership agreement, such PIK distributions continued to accumulate. On May 9, 2016, we issued 563,494 Class B Convertible Units to Holdings and 11,499 general partner units to our General Partner related to the quarters ended December 31, 2015 and March 31, 2016, which were not previously issued. On August 10, 2016, we issued 289,165 Class B Convertible Units to Holdings and 5,901 general partner units to our General Partner related to the quarter ended June 30, 2016. On November 14, 2016, we issued 294,226 Class B Convertible Units to Holdings and 6,004 general partner units to our General Partner related to the quarter ended September 30, 2016. On February 14, 2017, we issued 299,375 Class B Convertible Units to Holdings and 6,109 general partner units to our General Partner for the quarter ended December 31, 2016. Conversion Rights: The Class B Convertible Units are convertible into common units on a one-for-one basis and, once converted, will participate in cash distributions pari passu with all other common units. The conversion of Class B Convertible Units will occur on the date we (i) make a quarterly distribution equal to or greater than $0.44 per common unit, (ii) generate Class B Distributable Cash Flow (as defined in our Partnership Agreement) in an amount sufficient to pay the declared distribution on all units for the two quarters immediately preceding the date of conversion (the “measurement period”) and (iii) forecast paying a distribution equal to or greater than $0.44 per unit from forecasted Class B Distributable Cash Flow on all outstanding common units for the two quarters immediately following the measurement period. Voting Rights: The Class B Convertible Units generally have the same voting rights as common units, and have one vote for each common unit into which such units are convertible. Subordinated units Subordinated units represent limited partner interests in us and convert to common units at the end of the Subordination Period (as defined in our Partnership Agreement). The principal difference between our common units and our subordinated units is that in any quarter during the Subordination Period, holders of the subordinated units are not entitled to receive any distribution of available cash until the common units have received the minimum quarterly distribution plus any arrearages in the payment of the minimum quarterly distribution from prior quarters. Subordinated units do not accrue arrearages. Beginning with the third quarter of 2014, until such time we have a Distributable Cash Flow Ratio of at least 1.0, Holdings, the indirect holder of the subordinated units, has waived the right to receive distributions on any subordinated units that would cause the Distributable Cash Flow Ratio to be less than 1.0 . In addition, the Credit Agreement Amendment imposed additional restrictions on our ability to declare and pay quarterly cash distributions with respect to our subordinated units. See Note 7. General Partner Interests As defined by the Partnership Agreement, general partner units are not considered to be units (common or subordinated), but are representative of our general partner's 2.0% ownership interest in us. Our General Partner has received general partner unit PIK distributions in connection with the Class B Convertible Units. In connection with other equity issuances, our General Partner has made capital contributions in exchange for additional general partner units to maintain its 2.0% ownership interest in us. In connection with the 8,029,729 common units issued to Holdings on May 2, 2016 and the 359,459 common units issued to Holdings on May 13, 2016, our General Partner made capital contributions in exchange for 171,209 general partner units to maintain its 2.0% ownership interest in us.

PARTNERS' CAPITAL AND MEMBERS'

PARTNERS' CAPITAL AND MEMBERS' EQUITY	12 Months Ended
	Dec. 31, 2016
Partners' Capital Notes [Abstract]
PARTNERS' CAPITAL AND MEMBERS' EQUITY	PARTNERS' CAPITAL Ownership Our units outstanding as of December 31, 2016 are as follows (in units): Partners’ Capital Owned By Parent Public Holdings Class B General Common Common Convertible Subordinated Partner Units outstanding as of December 31, 2014 21,684,543 2,116,400 14,889,078 12,213,713 1,038,852 Common unit issuance related to the Holdings Acquisition — 4,500,000 — — — Board of Director grants 17,185 — — — — Vesting of LTIP units, net 102,491 — — — — In-kind distributions and general partner issuances to maintain 2.0% ownership — — 1,069,912 — 116,113 Units outstanding as of December 31, 2015 21,804,219 6,616,400 15,958,990 12,213,713 1,154,965 Vesting of LTIP units, net 205,797 — — — — In-kind distributions and issuances to general partner to maintain 2.0% ownership — — 1,146,885 — 433,233 Common unit issuances to Holdings related to equity cures — 19,875,674 — — — Units outstanding as of December 31, 2016 22,010,016 26,492,074 17,105,875 12,213,713 1,588,198 Common units Our common units represent limited partner interests in us. The holders of our common units are entitled to participate in our distributions (to the extent distributions are made) and are entitled to exercise the rights and privileges available to limited partners under our Partnership Agreement. In accordance with the requirements of the Equity Cure Agreement, Holdings was issued 8,029,729 common units on May 2, 2016 for the fourth quarter 2015 equity cure of $11.9 million and 359,459 common units on May 13, 2016 for the first quarter 2016 equity cure of $0.5 million . Pursuant to the Equity Cure Contribution Amendment, Holdings contributed $17.0 million to the Partnership in exchange for 11,486,486 common units on December 29, 2016. The proceeds of the $17.0 million contribution were used to pay down the outstanding balance under the Third A&R Revolving Credit Agreement and for general corporate purposes. On May 7, 2015, we completed the 2015 Holdings Acquisition for total consideration of $77.6 million , consisting of $15.0 million in cash and 4.5 million new common units, valued as of the date of closing and issued to Holdings. Class B Convertible Units As of December 31, 2016, the Class B Convertible Units consist of 17,105,875 units, inclusive of any Class B paid in-kind (“PIK”) Units issued. The Class B Convertible Units have the same rights, preferences and privileges, and are subject to the same duties and obligations, as our common units, with certain exceptions as noted below. Our Partnership Agreement does not allow additional Class B Convertible Units (other than Class B PIK Units) to be issued without the prior approval of our General Partner and the holders of a majority of the outstanding Class B Convertible Units. As of December 31, 2016, all of our outstanding Class B Convertible Units were indirectly owned by Holdings. Distribution Rights: The holders of the Class B Convertible Units will receive quarterly distributions in an amount equal to $0.3257 per unit paid in Class B PIK Units (based on a unit issuance price of $18.61 ) within 45 days after the end of each quarter. Our General Partner was entitled, and has exercised its right, to retain its 2.0% general partner interest in us in connection with the original issuance of Class B Convertible Units. In connection with future distributions of Class B PIK Units, the General Partner is entitled to a corresponding distribution to maintain its 2.0% general partner interest in us. We suspended distributions to holders of our Class B Convertible Units for the quarter ended December 31, 2015. However, under the terms of our Partnership agreement, such PIK distributions continued to accumulate. On May 9, 2016, we issued 563,494 Class B Convertible Units to Holdings and 11,499 general partner units to our General Partner related to the quarters ended December 31, 2015 and March 31, 2016, which were not previously issued. On August 10, 2016, we issued 289,165 Class B Convertible Units to Holdings and 5,901 general partner units to our General Partner related to the quarter ended June 30, 2016. On November 14, 2016, we issued 294,226 Class B Convertible Units to Holdings and 6,004 general partner units to our General Partner related to the quarter ended September 30, 2016. On February 14, 2017, we issued 299,375 Class B Convertible Units to Holdings and 6,109 general partner units to our General Partner for the quarter ended December 31, 2016. Conversion Rights: The Class B Convertible Units are convertible into common units on a one-for-one basis and, once converted, will participate in cash distributions pari passu with all other common units. The conversion of Class B Convertible Units will occur on the date we (i) make a quarterly distribution equal to or greater than $0.44 per common unit, (ii) generate Class B Distributable Cash Flow (as defined in our Partnership Agreement) in an amount sufficient to pay the declared distribution on all units for the two quarters immediately preceding the date of conversion (the “measurement period”) and (iii) forecast paying a distribution equal to or greater than $0.44 per unit from forecasted Class B Distributable Cash Flow on all outstanding common units for the two quarters immediately following the measurement period. Voting Rights: The Class B Convertible Units generally have the same voting rights as common units, and have one vote for each common unit into which such units are convertible. Subordinated units Subordinated units represent limited partner interests in us and convert to common units at the end of the Subordination Period (as defined in our Partnership Agreement). The principal difference between our common units and our subordinated units is that in any quarter during the Subordination Period, holders of the subordinated units are not entitled to receive any distribution of available cash until the common units have received the minimum quarterly distribution plus any arrearages in the payment of the minimum quarterly distribution from prior quarters. Subordinated units do not accrue arrearages. Beginning with the third quarter of 2014, until such time we have a Distributable Cash Flow Ratio of at least 1.0, Holdings, the indirect holder of the subordinated units, has waived the right to receive distributions on any subordinated units that would cause the Distributable Cash Flow Ratio to be less than 1.0 . In addition, the Credit Agreement Amendment imposed additional restrictions on our ability to declare and pay quarterly cash distributions with respect to our subordinated units. See Note 7. General Partner Interests As defined by the Partnership Agreement, general partner units are not considered to be units (common or subordinated), but are representative of our general partner's 2.0% ownership interest in us. Our General Partner has received general partner unit PIK distributions in connection with the Class B Convertible Units. In connection with other equity issuances, our General Partner has made capital contributions in exchange for additional general partner units to maintain its 2.0% ownership interest in us. In connection with the 8,029,729 common units issued to Holdings on May 2, 2016 and the 359,459 common units issued to Holdings on May 13, 2016, our General Partner made capital contributions in exchange for 171,209 general partner units to maintain its 2.0% ownership interest in us.

INCENTIVE COMPENSATION

INCENTIVE COMPENSATION	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
UNIT BASED COMPENSATION	INCENTIVE COMPENSATION Unit Based Compensation Long-Term Incentive Plan The 2012 Long-Term Incentive Plan ("LTIP") provides incentive awards to eligible officers, employees and directors of our General Partner. Awards granted to employees under the LTIP generally vest over a three year period in equal annual installments or in the event of a change in control, in either a common unit or an amount of cash equal to the fair market value of a common unit at the time of vesting, as determined by management at its discretion. These awards also include distribution equivalent rights that grant the holder the right to receive an amount equal to the cash distributions on common units during the period the award remains outstanding. On November 9, 2015, the holders of a majority of our limited partnership units approved an amendment to the LTIP to increase the number of common units that may be granted as awards by 4,500,000 units. The term of the LTIP was also extended to a period of 10 years following the amendment's adoption. The following table summarizes information regarding awards of units granted under the LTIP: Units Weighted-Average Fair Value at Grant Date Unvested - December 31, 2014 470,750 $ 20.45 Granted units 594,333 11.82 Forfeited units (204,530 ) 18.79 Units recaptured for tax withholdings (1) (47,592 ) 8.41 Vested Units (1) (125,041 ) 10.36 Unvested - December 31, 2015 687,920 $ 15.56 Granted units 47,500 3.56 Forfeited units (73,493 ) 15.35 Units recaptured for tax withholdings (1) (87,849 ) 16.42 Vested Units (1) (205,797 ) 15.92 Unvested - December 31, 2016 368,281 $ 14.91 (1) The weighted-average fair value price on the date of vesting for our vested units was $1.57 and $9.17 for the years ended December 31, 2016 and 2015. The weighted-average fair value price on the date of vesting for our units recaptured for tax withholdings was $1.52 and $8.41 for the years ended December 31, 2016 and 2015. For the years ended December 31, 2016 and 2015 , we granted awards under the LTIP, with an aggregate grant date fair value of $0.2 million and $7.0 million which we have classified as equity awards. As of December 31, 2016 and 2015 , we had total unamortized compensation expense of $3.1 million and $7.6 million related to unvested awards. Compensation expense associated with awards granted on March 10, 2015 of 84,423 units was recognized over a one -year vesting period, while compensation expense for the remaining awards is expected to be recognized over the three -year vesting period from each equity award's grant date. As of December 31, 2016 and 2015, we had 5,171,916 and 5,058,073 , respectively, units available for issuance under the LTIP. A grant of 84,423 units was made to the officers of our General Partner on March 10, 2015 that had a one -year vesting period rather than a three -year vesting period. These executive awards were not compensation earned for performance in 2015 . Unit Based Compensation Expense The following table summarizes information regarding recognized compensation expense, which is included in general and administrative and operations and maintenance expense on our statements of operations (in thousands): Year Ended December 31, 2016 2015 Unit-based compensation $ 3,523 $ 4,573 Employee Savings Plan We have employee savings plans under Sections 401(a) and 401(k) of the Internal Revenue Code, as amended, whereby employees of our General Partner may contribute a portion of their base compensation to the employee savings plan, subject to limits. We provide a matching contribution each payroll period equal to 100% of the employee's contribution up to the lesser of 6% of the employee's eligible compensation or $15,900 annually for the period. The following table summarizes information regarding contributions and the expense recognized for the matching contributions, which is included in general and administrative expense on our statements of operations (in thousands): Year Ended December 31, 2016 2015 Matching contributions expensed for employee savings plan $ 1,252 $ 709

REVENUES

REVENUES	12 Months Ended
	Dec. 31, 2016
Revenues [Abstract]
REVENUES	REVENUES We had revenues consisting of the following categories (in thousands): Year Ended December 31, 2016 2015 Sales of natural gas $ 271,302 $ 399,828 Sales of NGLs and condensate 158,968 154,478 Transportation, gathering and processing fees 113,482 138,717 Other 4,971 5,450 Total revenues $ 548,723 $ 698,473

EQUITY IN JOINT VENTURES (Notes

EQUITY IN JOINT VENTURES (Notes)	12 Months Ended
	Dec. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments and Joint Ventures Disclosure [Text Block]	INVESTMENTS IN JOINT VENTURES We own equity interests in three joint ventures with Targa Resources Corp. as our joint venture partner. T2 Eagle Ford Gathering Company LLC (“T2 Eagle Ford”), T2 LaSalle Gathering Company LLC (“T2 LaSalle”) and T2 Cogen operate pipelines and a cogeneration facility located in South Texas. We indirectly own a 50% interest in T2 Eagle Ford, a 50% interest in T2 Cogen and a 25% interest in T2 LaSalle. We pay our proportionate share of the joint ventures' operating costs, excluding depreciation and amortization, through lease capacity payments. As a result, our share of the joint ventures' losses is related primarily to the joint ventures' depreciation and amortization. Our maximum exposure to loss related to these joint ventures includes our equity investment, any additional capital contributions and our share of any operating expenses incurred by the joint ventures. We evaluate investments in joint ventures for impairment when factors indicate that a decrease in the value of the investment has occurred that is not temporary. During the fourth quarter of 2016, as part of firm wide cost-saving initiatives, management decided to significantly reduce the utilization of the T2 Cogen facility. In the immediate future, the T2 Cogen facility will be utilized only as a swing or backup facility for our Lone Star processing facility ("LS1"). As volumes are expected to increase in the ensuing years, management expects to need the generation capacity from the T2 Cogeneration facility to provide power to its LS1 facility. As the LS1 facility represents a more economical option to provide electricity to the Lone Star processing plant, management’s decision to reduce the utilization of the T2 Cogen substantially and as the electricity sales to FL Rich Gas Services represents the only source of revenue for T2 Cogen, the reduction in utilization significantly reduces the operating income associated with these assets. As a result in this change in the use of the T2 Cogen assets, T2 Cogen tested such assets for impairment, and recorded a $13.3 million impairment during the fourth quarter of 2016. We recorded our proportionate share (50%) of such impairment within equity in losses of joint venture investments. The joint ventures’ summarized financial data from their statements of operations for the years ended December 31, 2016 and 2015 is as follows (in thousands): Year Ended December 31, 2016 2015 Revenue T2 Eagle Ford $ 5,667 $ 6,850 T2 Cogen 2,556 2,437 T2 LaSalle 1,963 1,297 Net loss T2 Eagle Ford $ (19,312 ) $ (18,802 ) T2 Cogen (19,998 ) (5,837 ) T2 LaSalle (5,872 ) (5,860 ) Our equity in losses of joint venture investments is comprised of the following for the years ended December 31, 2016 and 2015 (in thousands): Year Ended December 31, 2016 2015 T2 Eagle Ford $ (9,656 ) $ (9,068 ) T2 Cogen (9,999 ) (2,919 ) T2 LaSalle (1,468 ) (1,465 ) Equity in losses of joint venture investments $ (21,123 ) $ (13,452 ) Our investments in joint ventures is comprised of the following as of December 31, 2016 and 2015 (in thousands): December 31, 2016 December 31, 2015 T2 Eagle Ford $ 101,669 $ 105,755 T2 Cogen 6,003 16,747 T2 LaSalle 16,424 18,024 Investments in joint ventures $ 124,096 $ 140,526 The joint ventures’ summarized balance sheet data is as follows (in thousands): December 31, 2016 December 31, 2015 T2 Cogen Current assets $ 603 $ 1,986 Property, plant and equipment, net 12,000 32,333 Total assets 12,603 34,319 Total liabilities 596 824 Total equity 12,006 33,495 Total liabilities and equity $ 12,603 $ 34,319 T2 Eagle Ford Current assets $ 2,517 $ 4,525 Property, plant and equipment, net 203,810 217,370 Total assets 206,327 221,895 Total liabilities 2,173 9,697 Total equity 204,154 212,198 Total liabilities and equity $ 206,327 $ 221,895 T2 LaSalle Current assets $ 1,046 $ 1,228 Property, plant and equipment, net 66,028 71,491 Total assets 67,074 72,719 Total liabilities 1,262 622 Total equity 65,812 72,097 Total liabilities and equity $ 67,074 $ 72,719 The joint ventures’ summarized financial data from their statements of operations for the years ended December 31, 2016 and 2015 is as follows (in thousands): Year Ended December 31, 2016 2015 Revenue T2 Eagle Ford $ 5,667 $ 6,850 T2 Cogen 2,556 2,437 T2 LaSalle 1,963 1,297 Net loss T2 Eagle Ford $ (19,312 ) $ (18,802 ) T2 Cogen (19,998 ) (5,837 ) T2 LaSalle (5,872 ) (5,860 ) Our equity in losses of joint venture investments is comprised of the following for the years ended December 31, 2016 and 2015 (in thousands): Year Ended December 31, 2016 2015 T2 Eagle Ford $ (9,656 ) $ (9,068 ) T2 Cogen (9,999 ) (2,919 ) T2 LaSalle (1,468 ) (1,465 ) Equity in losses of joint venture investments $ (21,123 ) $ (13,452 ) Our investments in joint ventures is comprised of the following as of December 31, 2016 and 2015 (in thousands): December 31, 2016 December 31, 2015 T2 Eagle Ford $ 101,669 $ 105,755 T2 Cogen 6,003 16,747 T2 LaSalle 16,424 18,024 Investments in joint ventures $ 124,096 $ 140,526 The joint ventures’ summarized balance sheet data is as follows (in thousands): December 31, 2016 December 31, 2015 T2 Cogen Current assets $ 603 $ 1,986 Property, plant and equipment, net 12,000 32,333 Total assets 12,603 34,319 Total liabilities 596 824 Total equity 12,006 33,495 Total liabilities and equity $ 12,603 $ 34,319 T2 Eagle Ford Current assets $ 2,517 $ 4,525 Property, plant and equipment, net 203,810 217,370 Total assets 206,327 221,895 Total liabilities 2,173 9,697 Total equity 204,154 212,198 Total liabilities and equity $ 206,327 $ 221,895 T2 LaSalle Current assets $ 1,046 $ 1,228 Property, plant and equipment, net 66,028 71,491 Total assets 67,074 72,719 Total liabilities 1,262 622 Total equity 65,812 72,097 Total liabilities and equity $ 67,074 $ 72,719

CONCENTRATION OF CREDIT RISK AN

CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE	12 Months Ended
	Dec. 31, 2016
Risks and Uncertainties [Abstract]
CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE	CONCENTRATION OF CREDIT RISK Our primary markets are in South Texas, Alabama and Mississippi. We have a concentration of revenues and trade accounts receivable due from customers engaged in the production, trading, distribution and marketing of natural gas and NGL products. These concentrations of customers may affect overall credit risk in that these customers may be affected similarly by changes in economic, regulatory or other factors. We analyze our customers’ historical financial and operational information before extending credit. Our top ten customers for the years ended December 31, 2016 and 2015 represent the following percentages of consolidated revenue: Year Ended December 31, 2016 2015 Top ten customers 53.5 % 54.2 % The percentage of total consolidated revenue for each customer that exceeded 10% of total revenues for the years ended December 31, 2016 and 2015 was as follows: Year Ended December 31, 2016 2015 Trafigura AG 10.7 % (a) (a) Information is not provided for periods for which the customer or producer was less than 10% of our consolidated revenue. For the years ended December 31, 2016 and 2015, we did not experience significant nonpayment for services. We had no allowance for uncollectible accounts receivable at December 31, 2016. We recorded an allowance for uncollectible accounts receivable of $0.1 million at December, 31, 2015, which was written off in 2016.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2016
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS

BASIS OF PRESENTATION (Policies

BASIS OF PRESENTATION (Policies)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The accompanying consolidated financial statements and related notes present the consolidated balance sheets as of December 31, 2016 and 2015 and the consolidated statements of operations, cash flows and changes in partners' capital for the years ended December 31, 2016 and 2015. We recognized the 2015 Holdings Acquisition (defined in Note 3) at Holdings’ historical cost because the acquisition was executed by entities under common control. Thus, the difference between consideration paid and Holdings’ historical cost (net book value) at May 7, 2015, the date on which the 2015 Holdings Acquisition closed, was recorded as a reduction to partners’ capital. Due to the common control aspect, the 2015 Holdings Acquisition was accounted for by the Partnership on an “as if pooled” basis for the periods during which common control existed which began on August 4, 2014. See Note 3. The accompanying consolidated financial statements were prepared in accordance with accounting principles generally accepted in the U.S. ("GAAP") and in accordance with the rules and regulations of the U.S. Securities and Exchange Commission. Our consolidated financial statements include the accounts of Southcross and its 100% owned subsidiaries. We eliminate all intercompany balances and transactions in preparing consolidated financial statements. We evaluate events that occur after the balance sheet date, but before the financial statements are issued, for potential recognition or disclosure. Based on the evaluation, we determined that there were no material subsequent events for recognition or disclosure other than those disclosed in this report. See Note 15.
Principles of Consolidation	Principles of Consolidation We consolidate entities when we have the ability to control or direct the operating and financial decisions of the entity or when we have a significant interest in the entity that gives us the ability to direct the activities that are significant to that entity. The determination of our ability to control, direct or exert significant influence over an entity involves the use of judgment. We do not have ownership in any consolidated variable interest entities.
Use of Estimates	Use of Estimates The preparation of the consolidated financial statements in conformity with GAAP requires management to make various estimates and assumptions that may affect the amounts of assets and liabilities, disclosures of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the period. Actual results may differ from those estimates.
Cash and Cash Equivalents	Cash and Cash Equivalents We consider all short-term investments with an original maturity of three months or less to be cash equivalents. At December 31, 2016 and 2015, except for amounts held in bank accounts to cover current payables, all of our cash equivalents were invested in short-term money market accounts and overnight sweep accounts.
Allowance for Doubtful Accounts	Allowance for Doubtful Accounts In evaluating the collectability of our accounts receivable, we perform credit evaluations of our new customers and adjust payment terms based upon payment history and each customer's current creditworthiness, as determined by our review of such customer's credit information. We extend credit on an unsecured basis to many of our customers. In the event of a bankruptcy filing by a customer, we will determine if we will legally be able to collect any of the outstanding balance as a secured or unsecured creditor, and based on this determination we will reserve against part, or all, of the outstanding balance. We had an allowance for uncollectible accounts receivable of $0.1 million at December 31, 2015
Debt Issuance Costs	Deferred financing costs are capitalized and amortized as interest expense under the effective interest method over the term of the related debt. The unamortized balance of deferred financing cost is included in long-term debt on the balance sheet.
Long-Lived Assets	Impairment of Long-Lived Assets We evaluate our long-lived assets by asset group, which include finite-lived intangible assets, for impairment when events or circumstances indicate that the asset group's carrying values may not be recoverable. These events include, but are not limited to, market declines that are believed to be other than temporary, changes in the manner in which we intend to use a long-lived asset or group, decisions to sell an asset and adverse changes in the legal or business environment such as adverse actions by regulators. If an event occurs, we evaluate the recoverability of our carrying value based on the long-lived asset group's ability to generate future cash flows on an undiscounted basis. If the undiscounted cash flows are not sufficient to recover the long-lived asset group's carrying value, or if we decide to sell a long-lived asset or group of assets, we adjust the carrying values of the asset downward, if necessary, to their estimated fair value. Our fair value estimates are based generally on assumptions market participants would use, including market data obtained through the sales process or an analysis of expected discounted cash flows. We had no impairment of our assets during the year ended December 31, 2016, but we recorded $0.5 million related to the write-off of software costs. During the year ended December 31, 2015, we recorded $7.1 million of impairment cost related primarily to a write-down of a spare turbine.
Asset Retirement Obligations		Asset Retirement Obligations We evaluate whether any future asset retirement obligations ("AROs") exist and estimate the costs for such AROs for certain future events. An ARO will be recorded in the periods where we can reasonably determine the settlement dates or the period in which the expense is incurred, and an estimated cost of the retirement obligation. Generally we do not have the intention of discontinuing the use of any significant assets or have a legal obligation to do so. Therefore, in these situations we do not have sufficient information to reasonably estimate any future AROs. No AROs were recorded for the years ended December 31, 2016 and 2015 .
Environmental Costs and Other Contingencies		Environmental Costs and Other Contingencies We recognize liabilities for environmental and other contingencies when we have an exposure that indicates it is both probable that a liability has been incurred and the amount of loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue a liability for that amount. Where the most likely outcome cannot be estimated, a range of potential losses is established and no specific amount in that range is more likely than any other, the low end of the range is accrued. No amounts were recorded as of December 31, 2016.
Revenue Recognition	Revenue Recognition Using the revenue recognition criteria of persuasive evidence of an exchange arrangement exists, delivery has occurred or services have been rendered and the price is fixed or determinable, we record natural gas and NGL sales revenue in the period when the physical product is delivered to the customer and in an amount based on the pricing terms of an executed contract. Our transportation, compression, processing, fractionation and other revenue is recognized in the period when the service is provided and represents our fee-based service revenue. In addition, collectability is evaluated on a customer-by-customer basis. New customers are subject to a credit review process, which evaluates the customers' financial position and their ability to pay. Our sale and purchase arrangements primarily are accounted for on a gross basis in the statements of operations. These transactions are contractual arrangements that establish the terms of the purchase of natural gas or NGLs at a specified location and the sale of natural gas or NGLs at a different location on the same or on another specified date. These transactions require physical delivery and transfer of the risk and reward of ownership are evidenced by title transfer, assumption of environmental risk, transportation scheduling, credit risk and counterparty nonperformance risk. We derive revenue in our business from the following types of arrangements: • Fixed-Fee. We receive a fixed-fee per unit of natural gas volume that we gather at the wellhead, process, treat, compress and/or transport for our customers, or we receive a fixed-fee per unit of NGL volume that we fractionate. Some of our arrangements also provide for a fixed-fee for guaranteed transportation capacity on our systems. • Fixed-Spread. Under these arrangements, we purchase natural gas and NGLs from producers or suppliers at receipt points on our systems at an index price plus or minus a fixed price differential and sell these volumes of natural gas and NGLs at delivery points off our systems at the same index price, plus or minus a fixed price differential. By entering into such back-to-back purchases and sales, we are able to mitigate our risk associated with changes in the general commodity price levels of natural gas and NGLs. We remain subject to variations in our fixed-spreads to the extent we are unable to precisely match volumes purchased and sold in a given time period or are unable to secure the supply or to produce or market the necessary volume of products at our anticipated differentials to the index price. • Commodity-Sensitive. In exchange for our processing services, we may remit to a customer a percentage of the proceeds from our sales, or a percentage of the physical volume, of residue natural gas and/or NGLs that result from our natural gas processing, or we may purchase NGLs from customers at set fixed NGL recoveries and retain the balance of the proceeds or physical commodity for our own account. These arrangements are generally combined with fixed-fee and fixed-spread arrangements for processing services and, therefore, represent only a portion of a processing contract's value. The revenues we receive from these arrangements directly correlate with fluctuating general commodity price levels of natural gas and NGLs and the volume of NGLs recovered relative to the fixed recovery obligations. Certain of our gathering and processing agreements provide for quarterly and annual minimum volume commitment ("MVC"). Under these MVCs, our customers agree to ship and/or process a minimum volume of production on our gathering systems or to pay a minimum monetary amount over certain periods during the term of the MVC. A customer must make a shortfall payment to us at the end of the contracted measurement period if its actual throughput volumes are less than its MVC for that period. Certain customers are entitled to utilize shortfall payments to offset gathering fees in one or more subsequent measurement periods to the extent that such customer's throughput volumes in a subsequent contracted measurement period exceed its MVC for that contracted measurement period. We recognize customer billings for obligations under their MVCs as revenue when the obligations are billable under the contract and the customer does not have the right to utilize shortfall payments to offset gathering fees in excess of its MVCs in subsequent periods. We record customer billings for obligations under their MVCs as deferred revenue when the customer has the right to utilize shortfall payments to offset gathering or processing fees in subsequent periods. We recognize deferred revenue under these arrangements in revenue once all contingencies or potential performance obligations associated with the related volumes have either (i) been satisfied through the gathering or processing of future excess volumes of natural gas, or (ii) expired (or lapsed) through the passage of time pursuant to the terms of the applicable natural gas gathering agreement. We classify deferred revenue as a current liability for arrangements where the expiration of a customer's right to utilize shortfall payments is 12 months or less.
Fair Value of Financial Instruments		Fair Value of Financial Instruments Accounting guidance requires the disclosure of the fair value of all financial instruments that are not otherwise recorded at fair value in the financial statements. At December 31, 2016 and 2015 , financial instruments recorded at contractual amounts that approximate fair value include certain funds on deposit, accounts receivable, other receivables and accounts payable and accrued liabilities. The fair values of such items are not materially sensitive to shifts in market interest rates because of the short term to maturity of these instruments. See Note 5.
Derivative Instruments		Derivative Instruments In our normal course of business, we enter into month-ahead commodity swap contracts in order to hedge economically our exposure to certain intra-month natural gas index pricing risk. We manage our interest rate risk through interest rate swaps and interest rate caps. See Note 5. Derivative financial instruments are recorded in the consolidated balance sheets at fair value, except for derivative contracts that qualify for and for which we have elected the normal purchase or normal sale exceptions, which are not reflected in the consolidated balance sheets or statements of operations prior to accrual of the settlement. If they qualify, we present our derivative assets and liabilities on a net basis. We did not have any derivative financial instruments designated as fair value or cash flow hedges for accounting purposes during the years ended December 31, 2016 and 2015 . Changes in our derivative financial instruments' fair values are recognized immediately in earnings. We do not hold or issue financial instruments or derivative financial instruments for trading purposes.
Unit-Based Compensation		Unit-Based Compensation Unit-based awards which settle in common units are classified as equity and are recognized in the financial statements over the vesting period at their grant date fair value. Unit-based awards which settle in cash are classified as liabilities and remeasured at every balance sheet date through settlement, such that the vested portion of the liability is adjusted to reflect its revised fair value through compensation expense. Currently, all awards granted under the Amended and Restated 2012 Long-Term Incentive Plan (the “LTIP”) will be settled in common units. Compensation expense associated with unit-based awards, adjusted for forfeitures, is recognized evenly from the date of the grant over the vesting period within operations and maintenance and general and administrative expense on our consolidated statements of operations.
Income Taxes		Income Taxes No provision for federal or state income taxes, except as noted below, is included in our statements of operations as such income is taxable directly to our partners. Each partner is responsible for its share of federal and state income tax. Net earnings for financial statement purposes may differ significantly from taxable income reportable to each partner as a result of differences between the tax basis and financial reporting basis of assets and liabilities. We are subject to the Texas margin tax which qualifies as an income tax under GAAP that requires us to recognize the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis. Our current tax liability will be assessed based on the gross revenue apportioned to Texas. For the years ended December 31, 2016 and 2015 , there were no material temporary differences.
Uncertain Tax Positions		Uncertain Tax Positions We evaluate the uncertainty in tax positions taken or expected to be taken in the course of preparing our consolidated financial statements to determine whether the tax positions are more likely than not of being sustained by the applicable tax authority. We believe that there are no uncertain tax positions and that no provision for income tax is required for these consolidated financial statements.
Earnings per Unit		Earnings per Unit Net loss per unit is calculated under the two-class method of computing earnings per unit when participating or multiple classes of securities exist. Under this method, undistributed earnings or losses for a period are allocated based on the contractual rights of each security to share in those earnings as if all of the earnings for the period had been distributed. Basic net loss per unit excludes dilution and is computed by dividing net loss attributable to limited partner common units by the weighted average number of limited partner common units outstanding during the period. Paid-in kind distributions are excluded from income available to common units in the calculation of basic earnings per unit. Dilutive net loss per unit reflects potential dilution from the potential issuance of limited partner common units. Dilutive net loss per unit is calculated using the treasury stock method. It is computed by dividing net loss attributable to limited partner common units by the weighted average number of limited partner common units outstanding during the period increased by the number of additional limited partner common units that would have been outstanding if the dilutive potential limited partner common units had been issued.
New Accounting Pronouncements	Recent Accounting Pronouncements Accounting standard-setting organizations frequently issue new or revised accounting pronouncements. We review and evaluate new pronouncements and existing pronouncements to determine their impact, if any, on our consolidated financial statements. We are evaluating the impact of each pronouncement on our consolidated financial statements. Adopted Accounting Pronouncements In 2014, a new standard was issued that updated existing going concern guidance under GAAP. The new guidance relates to defining management’s responsibility to evaluate whether there is substantial doubt about an organization’s ability to continue as a going concern. Related disclosure in the notes to the consolidated financial statements are required surrounding whether it is probable that the entity will not be able to meet its obligations as they become due within one year after the date that financial statements are issued. We adopted this standard during the year ended December 31, 2016. See Note 2. In February 2015, the Financial Accounting Standards Board (“FASB”) issued a pronouncement that amended the consolidation guidance with regard to variable interest entities and voting interest entities. The standard became effective in 2016 and amended the guidance and framework for determining whether a partial-interest owner in a subsidiary should consolidate and potentially revise their disclosures about certain money market funds that are not within the scope of the variable interest entity guidance and the required transition disclosures in the fiscal period in which a change in accounting principle is made. We adopted this standard, which did not have a material impact to us, in 2016. New Accounting Pronouncements In February 2016, a pronouncement was issued amending disclosure and presentation requirements for lessees and lessors on the face of the balance sheet. The pronouncement states that a lessee should recognize a liability to make lease payments and a right-of-use asset representing its right to use the underlying asset for the lease term. When measuring assets and liabilities arising from a lease, a lessee (and a lessor) should include payments to be made in optional periods only if the lessee is reasonably certain to exercise an option to extend the lease or not to exercise an option to terminate the lease. Similarly, optional payments to purchase the underlying asset should be included in the measurement of lease assets and lease liabilities only if the lessee is reasonably certain to exercise that purchase option. In addition, also consistent with the previous leases guidance, a lessee (and a lessor) should exclude most variable lease payments in measuring lease assets and lease liabilities, other than those that depend on an index or a rate or are in substance fixed payments. This standard will become effective beginning in 2019. In March 2016, a pronouncement was issued amending the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities and classification on the statement of cash flows. This standard will become effective beginning in 2017. In March 2016, the FASB issued a pronouncement amending the requirement to adopt retroactively the equity method of accounting. The pronouncement eliminates the requirement that when an investment qualifies for use of the equity method as a result of an increase in the level of ownership interest or degree of influence, an investor must adjust the investment, results of operations, and retained earnings retroactively on a step-by-step basis as if the equity method had been in effect during all previous periods that the investment had been held. The new guidance requires that the equity method investor add the cost of acquiring the additional interest in the investee to the current basis of the investor’s previously held interest and adopt the equity method of accounting as of the date the investment becomes qualified for equity method accounting. Therefore, upon qualifying for the equity method of accounting, no retroactive adjustment of the investment is required. In addition, the pronouncement requires that an entity that has an available-for sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in accumulated other comprehensive income at the date the investment becomes qualified for use of the equity method. This standard will become effective beginning in 2017. In 2014, a comprehensive new revenue recognition standard that will supersede substantially all existing revenue recognition guidance under GAAP was issued. The standard's core principle is that a company will recognize revenue when it transfers promised goods or services to customers and in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. In April 2016, the FASB issued an accounting pronouncement which updates the identifying performance obligations and licensing implementation guidance. We are currently evaluating our contract mix, developing our implementation plan, and assessing the impact to our existing accounting policies and controls that will be impacted by the standard. The standard will become effective beginning in 2018. In May 2016, the FASB issued a pronouncement for the new revenue recognition guidance on assessing collectability, presentation of sales taxes, non-cash consideration, completed contracts and contract modifications. The pronouncement is intended to reduce the potential for diversity in practice at initial application and cost and complexity on an ongoing basis. The standard will become effective beginning in 2018. In August 2016, the FASB issued a pronouncement amending the presentation of how certain cash receipts and cash payments are presented and classified in the statement of cash flows. The standard will become effective at the beginning of 2018.

SUPPLEMENTAL CASH FLOW INFORMAT

SUPPLEMENTAL CASH FLOW INFORMATION Supplemental Cash Flow Information (Policies)	12 Months Ended
	Dec. 31, 2016
Statement of Cash Flows [Abstract]
Interest Capitalization, Policy [Policy Text Block]	We capitalize interest on projects during their construction period. Once a project is placed in service, capitalized interest, as a component of the total cost of the construction, is depreciated over the estimated useful life of the asset constructed.

ACQUISITIONS (Tables)

ACQUISITIONS (Tables) - $ / shares	12 Months Ended
	Dec. 31, 2015	May 07, 2015
Business Acquisition [Line Items]
Business Acquisition, Share Price		$ 13.92
Schedule of unaudited pro forma financial information Predecessor includes adjustments for income from operations, including depreciation and amortization	Revenues and net income for the previously separate entities and the combined amounts for the year ended December 31, 2015, are as follows (in thousands): Year Ended December 31, 2015 Partnership revenues $ 691,424 Valley Wells System and Compression Assets revenue 7,049 Combined revenues $ 698,473 Partnership net loss $ (51,235 ) Valley Wells System and Compression Assets net loss (4,258 ) Combined net loss $ (55,493 )

EARNINGS PER LIMITED PARTNER 29

EARNINGS PER LIMITED PARTNER UNIT AND DISTRIBUTIONS (Tables)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Earnings Per Share [Abstract]
Schedule of reconciliation of net loss attributable to limited partners and limited partner units used in basic and diluted earnings per unit calculations	The following is a reconciliation of net loss attributable to limited partners and the limited partner units used in the basic and diluted earnings per unit calculations for the years ended December 31, 2016 and 2015 (in thousands, except unit and per unit data): Year Ended December 31, 2016 2015 (1) Net loss $ (94,948 ) $ (55,493 ) General partner unit in-kind distribution (47 ) (164 ) Net loss attributable to Holdings — (4,258 ) Net loss attributable to partners $ (94,995 ) $ (51,399 ) General partner's interest (1) $ (1,911 ) $ (1,084 ) Class B Convertible limited partner interest (1) (24,383 ) (14,225 ) Limited partners' interest (1) Common $ (50,612 ) $ (24,790 ) Subordinated (18,089 ) (11,300 ) _____________________________________________________________ (1) General Partner's and limited partners’ interests are calculated based on the allocation of net losses for the period, net of the General Partner unit in-kind distributions. The Class B Convertible Unit ("Class B Convertible Units") interest is calculated based on the allocation of only net losses for the period. Year Ended December 31, Common Units 2016 2015 Interest in net loss $ (50,612 ) $ (24,790 ) Effect of dilutive units - numerator (1) — — Dilutive interest in net loss $ (50,612 ) $ (24,790 ) Weighted-average units - basic 34,160,860 26,780,825 Effect of dilutive units - denominator(1) — — Weighted-average units - dilutive 34,160,860 26,780,825 Basic and diluted net loss per common unit $ (1.48 ) $ (0.93 ) Year Ended December 31, Subordinated Units 2016 2015 Interest in net loss $ (18,089 ) $ (11,300 ) Effect of dilutive units - numerator (1) — — Dilutive interest in net loss $ (18,089 ) $ (11,300 ) Weighted-average units - basic 12,213,713 12,213,713 Effect of dilutive units - denominator (1) — — Weighted-average units - dilutive 12,213,713 12,213,713 Basic and diluted net loss per subordinated unit $ (1.48 ) $ (0.93 ) ____________________________________________________________________________ (1) Because we had a net loss for all periods for common units and the subordinated units, the effect of the dilutive units would be anti-dilutive to the per unit calculation. Therefore, the weighted average units outstanding are the same for basic and dilutive net loss per unit for those periods. The weighted average units that were not included in the computation of diluted per unit amounts were 19,453 and 17,168 and unvested awards granted under our LTIP for the years ended December 31, 2016 and 2015, respectively.
Distributions Made to Limited Partners and General Partner		The following table represents our distributions paid for previous periods (in thousands, except per unit data): Distributions Attributable to the Per Unit Limited Partners Payment Date Quarter Ended Distribution Common Subordinated General Partner Total 2015 November 13, 2015 September 30, 2015 $ 0.40 $ 11,368 $ — $ 459 $ 11,827 August 14, 2015 June 30, 2015 0.40 11,325 — 457 11,782 May 14, 2015 March 31, 2015 0.40 9,520 — 418 9,938
Schedule of Paid In-Kind Distributions		The following table represents the PIK distribution paid on the Class B Convertible Units for periods ended December 31, 2015 and December 31, 2016 (in thousands, except per unit and in-kind distribution units): Payment Date Attributable to the Quarter Ended Per Unit Distribution In-Kind Class B Convertible Unit In-Kind Class B Convertible Distributions (1) In-Kind Unit to General Partner In-Kind General Partner Distribution Value (1) 2016 February 14, 2017 December 31, 2016 $ 0.3257 299,375 $ 404 6,109 $ 8 November 24, 2016 September 30, 2016 0.3257 294,226 433 6,004 9 August 10, 2016 June 30, 2016 0.3257 289,165 581 5,901 12 May 9, 2016 (2) 0.3257 563,494 1,293 11,499 26 2015 November 13, 2015 September 30, 2015 $ 0.3257 274,478 $ 1,353 5,601 $ 28 August 14, 2015 June 30, 2015 0.3257 269,758 2,994 5,505 61 May 14, 2015 March 31, 2015 0.3257 265,118 3,712 5,410 76 (1) The fair value was calculated as required, based on the common unit price at the quarter end date for the period attributable to the distribution, multiplied by the number of units distributed. s

FINANCIAL INSTRUMENTS (Tables)

FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2016
Derivatives
Schedule of the fair value of the interest rate cap and interest rate swap liabilities	Our interest rate swap position was as follows (in thousands): Estimated Fair Value Notional Amount Fixed Rate Effective Date Maturity Date December 31, 2016 100,000 1.195 % June 30, 2015 January 1, 2017 (15 ) Effectively, we enter into interest rate cap contracts to limit our London Interbank Offered Rate ("LIBOR")-based interest rate risk on the portion of debt hedged at the contracted cap rate. Our interest rate cap position was as follows (in thousands): Estimated Fair Value Notional Amount Cap Rate Effective Date Maturity Date December 31, 2016 $ 20,000 1.500 % December 31, 2014 December 31, 2016 — 80,000 3.000 % June 30, 2015 June 30, 2017 — 50,000 3.000 % December 31, 2015 December 31, 2017 — 50,000 3.000 % June 30, 2016 June 30, 2018 4 40,000 3.000 % December 31, 2016 January 1, 2018 — 40,000 3.000 % December 31, 2016 July 1, 2018 3 40,000 3.000 % December 31, 2016 January 1, 2019 14 $ 21 In December 2016, we entered into three new interest rate cap contracts for $40.0 million notional values, each effective December 31, 2016. The new interest rate cap contracts provide for maturity dates of January 1, 2018, July 1, 2018 and January 1, 2019. The contracts effectively cap our LIBOR-based interest rate on the portion of debt at 3.0% . These interest rate derivatives are not designated as cash flow hedging instruments for accounting purposes and as a result, changes in the fair value are recognized in interest expense immediately. The fair value of our interest rate derivative transactions is determined based on a discounted cash flow method using contractual terms of the transactions. The floating coupon rate is based on observable rates consistent with the frequency of the interest cash flows. We have elected to present our interest rate derivatives net on the balance sheets. There was no effect of offsetting on the balance sheets as of December 31, 2016 and 2015. The fair values of our interest rate derivative transactions were as follows (in thousands): Significant Other Observable Inputs (Level 2) Fair Value Measurement as of December 31, 2016 December 31, 2015 Current interest rate derivative assets $ 2 $ 6 Non-current interest rate derivative assets 2 4 Current interest rate derivative (liabilities) (15 ) (169 ) Total interest rate derivatives $ (11 ) $ (159 )
Interest rate cap contract
Derivatives
Schedule of amounts recognized in the statement of operations	The realized and unrealized amounts recognized in interest expense associated with derivatives were as follows (in thousands): Year Ended December 31, 2016 2015 Unrealized gain on interest rate derivatives $ (147 ) $ (1 ) Realized loss on interest rate derivatives 283 416
Commodity Swaps
Derivatives
Schedule of amounts recognized in the statement of operations	The realized and unrealized gain/loss on these derivatives, recognized in revenues in our statements of operations, were as follows (in thousands): Year ended December 31, 2016 2015 Realized gain on commodity swap derivatives $ — $ 214 Unrealized loss on commodity swap derivatives — (111 )

LONG-LIVED ASSETS (Tables)

LONG-LIVED ASSETS (Tables)	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
Schedule of property, plant and equipment	Property, plant and equipment consist of the following (in thousands): Estimated Useful Life As of December 31, 2016 2015 Pipelines 15-30 $ 552,540 $ 542,790 Gas processing, treating and other plants 15 509,840 547,253 Compressors 5-15 72,054 72,750 Rights of way and easements 15 49,998 46,692 Furniture, fixtures and equipment 5 9,269 9,252 Capital lease vehicles 3-5 1,713 2,442 Total property, plant and equipment 1,195,414 1,221,179 Accumulated depreciation and amortization (262,709 ) (212,991 ) Total 932,705 1,008,188 Construction in progress 16,150 32,214 Land and other 22,431 25,599 Property, plant and equipment, net $ 971,286 $ 1,066,001

LONG-TERM DEBT (Tables)

LONG-TERM DEBT (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Schedule of long-term debt	Our outstanding debt and related information at December 31, 2016 and 2015 is as follows (in thousands): As of December 31, 2016 2015 Revolving credit facility due 2019 $ 122,555 $ 181,695 Term loans (including original issue discount of $1.5 million and $1.8 million as of December 31, 2016 and 2015, respectively) due 2021 437,291 441,464 Total long-term debt (including current portion) 559,846 623,159 Current portion of long-term debt (4,500 ) (4,500 ) Debt issuance costs (11,474 ) (14,141 ) Total long-term debt $ 543,872 $ 604,518 Outstanding letters of credit $ 19,378 $ 18,305 Remaining unused borrowings $ 3,067 $ — Year Ended December 31, 2016 2015 Weighted average interest rate 5.25 % 5.16 % Average outstanding borrowings $ 591,970 $ 564,568 Maximum borrowings $ 628,055 $ 624,945

LONG-TERM DEBT Long-Term Debt_

LONG-TERM DEBT Long-Term Debt: Deferred financing costs (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Schedule of Debt Issuance Costs [Table Text Block]	Changes in deferred financing costs are as follows (in thousands): Year Ended December 31, 2016 2015 Deferred financing costs, January 1 $ 14,141 $ 16,602 Capitalization of deferred financing costs 1,366 698 Write-off of deferred financing costs (1,006 ) — Amortization of deferred financing costs (3,027 ) (3,159 ) Deferred financing costs, December 31 $ 11,474 $ 14,141

COMMITMENTS AND CONTINGENT LI34

COMMITMENTS AND CONTINGENT LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Schedule of Capital Lease Obligations [Table Text Block]	he capital lease obligation amounts included on the balance sheets were as follows (in thousands): December 31, 2016 December 31, 2015 Other current liabilities $ 396 $ 362 Other non-current liabilities 497 522 Total $ 893 $ 884
Schedule of future minimum annual rental commitments under capital and operating leases	Future minimum annual rental commitments under our capital and operating leases at December 31, 2016 were as follows (in thousands): Years Ending December 31, Capital Leases Operating Leases 2017 $ 396 $ 3,634 2018 291 3,477 2019 145 3,409 2020 61 2,912 2021 — 1,148 Thereafter — 4,912 Total future payments 893 $ 19,492 Less: Imputed interest $ — Future lease payments $ 893

TRANSACTIONS WITH RELATED PAR35

TRANSACTIONS WITH RELATED PARTIES (Tables)	12 Months Ended
	Dec. 31, 2015
Related Party Transactions [Abstract]
Schedule of Related Party Transactions [Table Text Block]	Year Ended December 31, 2016 2015 Charlesbank Capital Partners, LLC (1) $ 97 $ 148 EIG 62 64 Tailwater 61 64 Total fees and expenses paid for director services to affiliated entities $ 220 $ 276 We incurred expenses related to these reimbursements as follows (in thousands): Year Ended December 31, 2016 2015 Reimbursements included in general and administrative expenses $ 11,894 $ 15,790 Reimbursements included in operations and maintenance expenses 20,872 20,045 Total reimbursements to our General Partner and its affiliates $ 32,766 $ 35,835

PARTNERS' CAPITAL AND MEMBERS36

PARTNERS' CAPITAL AND MEMBERS' EQUITY - (Tables)	12 Months Ended
	Dec. 31, 2016
Partners' Capital [Abstract]
Schedule of Stockholders Equity [Table Text Block]	Our units outstanding as of December 31, 2016 are as follows (in units): Partners’ Capital Owned By Parent Public Holdings Class B General Common Common Convertible Subordinated Partner Units outstanding as of December 31, 2014 21,684,543 2,116,400 14,889,078 12,213,713 1,038,852 Common unit issuance related to the Holdings Acquisition — 4,500,000 — — — Board of Director grants 17,185 — — — — Vesting of LTIP units, net 102,491 — — — — In-kind distributions and general partner issuances to maintain 2.0% ownership — — 1,069,912 — 116,113 Units outstanding as of December 31, 2015 21,804,219 6,616,400 15,958,990 12,213,713 1,154,965 Vesting of LTIP units, net 205,797 — — — — In-kind distributions and issuances to general partner to maintain 2.0% ownership — — 1,146,885 — 433,233 Common unit issuances to Holdings related to equity cures — 19,875,674 — — — Units outstanding as of December 31, 2016 22,010,016 26,492,074 17,105,875 12,213,713 1,588,198

INCENTIVE COMPENSATION (Tables)

INCENTIVE COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of information regarding the Incentive Plan unit activity	The following table summarizes information regarding awards of units granted under the LTIP: Units Weighted-Average Fair Value at Grant Date Unvested - December 31, 2014 470,750 $ 20.45 Granted units 594,333 11.82 Forfeited units (204,530 ) 18.79 Units recaptured for tax withholdings (1) (47,592 ) 8.41 Vested Units (1) (125,041 ) 10.36 Unvested - December 31, 2015 687,920 $ 15.56 Granted units 47,500 3.56 Forfeited units (73,493 ) 15.35 Units recaptured for tax withholdings (1) (87,849 ) 16.42 Vested Units (1) (205,797 ) 15.92 Unvested - December 31, 2016 368,281 $ 14.91
Schedule of Unit Based Compensation Expense	The following table summarizes information regarding recognized compensation expense, which is included in general and administrative and operations and maintenance expense on our statements of operations (in thousands): Year Ended December 31, 2016 2015 Unit-based compensation $ 3,523 $ 4,573
Schedule of Employer's Matching Contributions	The following table summarizes information regarding contributions and the expense recognized for the matching contributions, which is included in general and administrative expense on our statements of operations (in thousands): Year Ended December 31, 2016 2015 Matching contributions expensed for employee savings plan $ 1,252 $ 709

REVENUES (Tables)

REVENUES (Tables)	12 Months Ended
	Dec. 31, 2016
Revenues [Abstract]
Schedule of revenues by category	We had revenues consisting of the following categories (in thousands): Year Ended December 31, 2016 2015 Sales of natural gas $ 271,302 $ 399,828 Sales of NGLs and condensate 158,968 154,478 Transportation, gathering and processing fees 113,482 138,717 Other 4,971 5,450 Total revenues $ 548,723 $ 698,473

EQUITY IN JOINT VENTURES (Table

EQUITY IN JOINT VENTURES (Tables)	12 Months Ended
	Dec. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments and Joint Ventures Disclosure [Text Block]	INVESTMENTS IN JOINT VENTURES We own equity interests in three joint ventures with Targa Resources Corp. as our joint venture partner. T2 Eagle Ford Gathering Company LLC (“T2 Eagle Ford”), T2 LaSalle Gathering Company LLC (“T2 LaSalle”) and T2 Cogen operate pipelines and a cogeneration facility located in South Texas. We indirectly own a 50% interest in T2 Eagle Ford, a 50% interest in T2 Cogen and a 25% interest in T2 LaSalle. We pay our proportionate share of the joint ventures' operating costs, excluding depreciation and amortization, through lease capacity payments. As a result, our share of the joint ventures' losses is related primarily to the joint ventures' depreciation and amortization. Our maximum exposure to loss related to these joint ventures includes our equity investment, any additional capital contributions and our share of any operating expenses incurred by the joint ventures. We evaluate investments in joint ventures for impairment when factors indicate that a decrease in the value of the investment has occurred that is not temporary. During the fourth quarter of 2016, as part of firm wide cost-saving initiatives, management decided to significantly reduce the utilization of the T2 Cogen facility. In the immediate future, the T2 Cogen facility will be utilized only as a swing or backup facility for our Lone Star processing facility ("LS1"). As volumes are expected to increase in the ensuing years, management expects to need the generation capacity from the T2 Cogeneration facility to provide power to its LS1 facility. As the LS1 facility represents a more economical option to provide electricity to the Lone Star processing plant, management’s decision to reduce the utilization of the T2 Cogen substantially and as the electricity sales to FL Rich Gas Services represents the only source of revenue for T2 Cogen, the reduction in utilization significantly reduces the operating income associated with these assets. As a result in this change in the use of the T2 Cogen assets, T2 Cogen tested such assets for impairment, and recorded a $13.3 million impairment during the fourth quarter of 2016. We recorded our proportionate share (50%) of such impairment within equity in losses of joint venture investments. The joint ventures’ summarized financial data from their statements of operations for the years ended December 31, 2016 and 2015 is as follows (in thousands): Year Ended December 31, 2016 2015 Revenue T2 Eagle Ford $ 5,667 $ 6,850 T2 Cogen 2,556 2,437 T2 LaSalle 1,963 1,297 Net loss T2 Eagle Ford $ (19,312 ) $ (18,802 ) T2 Cogen (19,998 ) (5,837 ) T2 LaSalle (5,872 ) (5,860 ) Our equity in losses of joint venture investments is comprised of the following for the years ended December 31, 2016 and 2015 (in thousands): Year Ended December 31, 2016 2015 T2 Eagle Ford $ (9,656 ) $ (9,068 ) T2 Cogen (9,999 ) (2,919 ) T2 LaSalle (1,468 ) (1,465 ) Equity in losses of joint venture investments $ (21,123 ) $ (13,452 ) Our investments in joint ventures is comprised of the following as of December 31, 2016 and 2015 (in thousands): December 31, 2016 December 31, 2015 T2 Eagle Ford $ 101,669 $ 105,755 T2 Cogen 6,003 16,747 T2 LaSalle 16,424 18,024 Investments in joint ventures $ 124,096 $ 140,526 The joint ventures’ summarized balance sheet data is as follows (in thousands): December 31, 2016 December 31, 2015 T2 Cogen Current assets $ 603 $ 1,986 Property, plant and equipment, net 12,000 32,333 Total assets 12,603 34,319 Total liabilities 596 824 Total equity 12,006 33,495 Total liabilities and equity $ 12,603 $ 34,319 T2 Eagle Ford Current assets $ 2,517 $ 4,525 Property, plant and equipment, net 203,810 217,370 Total assets 206,327 221,895 Total liabilities 2,173 9,697 Total equity 204,154 212,198 Total liabilities and equity $ 206,327 $ 221,895 T2 LaSalle Current assets $ 1,046 $ 1,228 Property, plant and equipment, net 66,028 71,491 Total assets 67,074 72,719 Total liabilities 1,262 622 Total equity 65,812 72,097 Total liabilities and equity $ 67,074 $ 72,719 The joint ventures’ summarized financial data from their statements of operations for the years ended December 31, 2016 and 2015 is as follows (in thousands): Year Ended December 31, 2016 2015 Revenue T2 Eagle Ford $ 5,667 $ 6,850 T2 Cogen 2,556 2,437 T2 LaSalle 1,963 1,297 Net loss T2 Eagle Ford $ (19,312 ) $ (18,802 ) T2 Cogen (19,998 ) (5,837 ) T2 LaSalle (5,872 ) (5,860 ) Our equity in losses of joint venture investments is comprised of the following for the years ended December 31, 2016 and 2015 (in thousands): Year Ended December 31, 2016 2015 T2 Eagle Ford $ (9,656 ) $ (9,068 ) T2 Cogen (9,999 ) (2,919 ) T2 LaSalle (1,468 ) (1,465 ) Equity in losses of joint venture investments $ (21,123 ) $ (13,452 ) Our investments in joint ventures is comprised of the following as of December 31, 2016 and 2015 (in thousands): December 31, 2016 December 31, 2015 T2 Eagle Ford $ 101,669 $ 105,755 T2 Cogen 6,003 16,747 T2 LaSalle 16,424 18,024 Investments in joint ventures $ 124,096 $ 140,526 The joint ventures’ summarized balance sheet data is as follows (in thousands): December 31, 2016 December 31, 2015 T2 Cogen Current assets $ 603 $ 1,986 Property, plant and equipment, net 12,000 32,333 Total assets 12,603 34,319 Total liabilities 596 824 Total equity 12,006 33,495 Total liabilities and equity $ 12,603 $ 34,319 T2 Eagle Ford Current assets $ 2,517 $ 4,525 Property, plant and equipment, net 203,810 217,370 Total assets 206,327 221,895 Total liabilities 2,173 9,697 Total equity 204,154 212,198 Total liabilities and equity $ 206,327 $ 221,895 T2 LaSalle Current assets $ 1,046 $ 1,228 Property, plant and equipment, net 66,028 71,491 Total assets 67,074 72,719 Total liabilities 1,262 622 Total equity 65,812 72,097 Total liabilities and equity $ 67,074 $ 72,719

CONCENTRATION OF CREDIT RISK 40

CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE (Tables)	12 Months Ended
	Dec. 31, 2016
Risks and Uncertainties [Abstract]
Schedules of Concentration of Risk, Consolidated Revenue	Our top ten customers for the years ended December 31, 2016 and 2015 represent the following percentages of consolidated revenue: Year Ended December 31, 2016 2015 Top ten customers 53.5 % 54.2 % The percentage of total consolidated revenue for each customer that exceeded 10% of total revenues for the years ended December 31, 2016 and 2015 was as follows: Year Ended December 31, 2016 2015 Trafigura AG 10.7 % (a)

SUPPLEMENTAL CASH FLOW INFORM41

SUPPLEMENTAL CASH FLOW INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2016
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	SUPPLEMENTAL INFORMATION Supplemental Cash Flow Information (in thousands) Year Ended December 31, 2016 2015 Supplemental Disclosures: Cash paid for interest $ 32,459 $ 32,293 Cash received for tax refunds 52 58 Supplemental schedule of non-cash investing and financing activities: Accounts payable related to capital expenditures 3,186 5,773 Capital lease obligation 423 378 Accrued distribution equivalent rights on the LTIP units 11 689 Class B Convertible unit in-kind distributions 2,307 8,059 Operating expenses for Valley Wells' assets due from Holdings — 1,647 Net assets contributed in Holdings drop-down acquisition in excess of consideration paid — 29,716 Purchase of assets in Holdings drop-down acquisition — 62,640 Net liabilities assumed by Holdings in Holdings drop-down acquisition — 1,436 Receivable from Holdings for purchase of office leasehold improvements — 2,320 PIK interest 260 — Common unit issuances to General Partner related to equity cures and equity contributions 854 — Capitalization of Interest Cost We capitalize interest on projects during their construction period. Once a project is placed in service, capitalized interest, as a component of the total cost of the construction, is depreciated over the estimated useful life of the asset constructed. We incurred the following interest costs (in thousands): Year Ended December 31, 2016 2015 Total interest costs $ 36,066 $ 34,517 Capitalized interest included in property, plant and equipment, net (900 ) (1,779 ) Interest expense $ 35,166 $ 32,738 Southcross Assets Considered Leases to Third Parties We have pipelines that transport natural gas to two power plants in Nueces County, Texas under fixed-fee contracts. The contracts have a primary term through 2029 and an option to extend the agreement by an additional term of up to ten years. These contracts are considered operating leases under the applicable accounting guidance. Future minimum annual demand payment receipts under these agreements as of December 31, 2016 were as follows: $5.6 million in 2017; $2.2 million in 2018; $2.2 million in 2019; $2.2 million in 2020 and $13.1 million thereafter. The revenue for the demand payments is recognized on a straight-line basis over the term of the contract. The demand fee revenues under the contracts were $2.6 million and $2.6 million for the years ended December 31, 2016 and 2015, respectively, and have been included within transportation, gathering and processing fees within Note 12. These amounts do not include variable fees based on the actual gas volumes delivered under the contracts. Variable fees recognized in revenues within transportation, gathering and processing fees within Note 12 were $3.0 million and $3.0 million for the years ended December 31, 2016 and 2015, respectively. Deferred revenue associated with these agreement was $8.5 million and $5.5 million at December 31, 2016 and 2015, respectively.
Schedule of Interest Costs Incurred	We incurred the following interest costs (in thousands): Year Ended December 31, 2016 2015 Total interest costs $ 36,066 $ 34,517 Capitalized interest included in property, plant and equipment, net (900 ) (1,779 ) Interest expense $ 35,166 $ 32,738

ORGANIZATION AND DESCRIPTION 42

ORGANIZATION AND DESCRIPTION OF BUSINESS (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016segment	Dec. 31, 2015USD ($)
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Lenders percentage ownership of Holdings	one-third
Number of Processing Plant	two
Number of fractionation plants	one
Number of reportable segments | segment	1
Other Additional Capital | $		$ 50

BASIS OF PRESENTATION (Details)

BASIS OF PRESENTATION (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accounting Policies [Abstract]
fines and penalties paid	$ 0
Basis of Presentation
Ownership interest in consolidated subsidiaries (as a percent)	100.00%
Long-Lived Assets
Expected useful lives of long-term supply and gas gathering contracts	30 years
Asset Impairment Charges	$ 476,000	$ 7,067,000
Accounts Receivable
Allowance for Doubtful Accounts Receivable, Current		$ 100,000	$ 0
Asset Retirement Obligation [Abstract]
Asset retirement obligation	$ 0

BASIS OF PRESENTATION BASIS OF

BASIS OF PRESENTATION BASIS OF PRESENTATION - Interest Expense (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Accounting Policies [Abstract]
Interest Expense	$ 900	$ 1,779

BASIS OF PRESENTATION BASIS O45

BASIS OF PRESENTATION BASIS OF PRESENTATION - Deferred Financing Costs (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Deferred Financing Costs [Roll Forward]
Deferred financing costs, beginning balance	$ 14,141	$ 16,602
Capitalization of deferred financing costs	1,366	698
Amortization of deferred financing costs		(3,159)
Deferred financing costs, ending balance	$ 11,474	$ 14,141

LIQUIDITY CONSIDERATIONS AND 46

LIQUIDITY CONSIDERATIONS AND EQUITY OFFERINGS (Details)	Apr. 12, 2013USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)d$ / shares	Aug. 04, 2014USD ($)
Schedule of Capitalization, Long-term Debt [Line Items]
Holdings capital commitment		$ 17,000,000
Document Period End Date			Dec. 31, 2016
Amortization of financing costs				$ (3,159,000)
Other Additional Capital				$ 50,000,000
VWAP time window | d				15
VWAP floor | $ / shares				$ 0.89
VWAP Ceiling | $ / shares				$ 1.48
Senior Notes, Noncurrent				$ 14,000,000
Debt Instrument, Interest Rate, Stated Percentage				7.00%
Holdings common units received for capital commitment		11,486,486,000,000
Investment agreement capital commitment from Holdings		$ 15,000,000
Volume weighted average price of common units		93.00%
Investment agreement interest rate		12.50%
Equity Cure Funding			$ 12,400,000
Letter of Credit [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Maximum borrowing capacity	$ 75,000,000	$ 200,000,000	$ 200,000,000		$ 75,000,000
General Partner [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Ownership interest held by limited partners (as a percent)	2.00%

ACQUISITIONS (Details)

ACQUISITIONS (Details) $ / shares in Units, $ in Thousands	May 08, 2015USD ($)	May 07, 2015USD ($)$ / shares	Aug. 04, 2014shares	Dec. 31, 2016USD ($)segment$ / shares	Dec. 31, 2015USD ($)$ / shares	Sep. 30, 2015shares	Jun. 30, 2015shares
ACQUISITIONS
Document Period End Date				Dec. 31, 2016
Payments to Acquire Businesses, Gross		$ 77,600
Purchase Price - Cash
Payments to Acquire Businesses, Net of Cash Acquired		$ 15,000
Fair value of identifiable assets acquired
number of joint ventures | segment				3
Unaudited Pro Forma Information
Revenue				$ 548,723	$ 698,473
Net income				$ (94,948)	$ (55,493)
Basic and diluted net loss per subordinated unit (in dollars per share) | $ / shares				$ (1.48)	$ (0.93)
Total revenue					$ 691,424
Net income					(51,235)
Business Combination, Consideration Transferred					15,000
Revenue from Related Parties				$ 97,500	94,700
Business Acquisition, Share Price | $ / shares		$ 13.92
valley wells [Member]
Fair value of identifiable assets acquired
Business Combination, Bargain Purchase, Gain Recognized, Amount	$ 29,716
Unaudited Pro Forma Information
Revenue from Related Parties					7,049
Related Party Transaction, Other Revenues from Transactions with Related Party					4,258
Common Units [Member]
Purchase Price - Cash
Common Stock, Shares, Issued | shares						4,500,000	4,500,000
Class B Convertible Units [Member]
Fair value of identifiable assets acquired
Business Combination, Bargain Purchase, Gain Recognized, Amount	7,929
Unaudited Pro Forma Information
Net income				(24,383)	(14,225)
Subordinated Limited Partners [Member]
Fair value of identifiable assets acquired
Business Combination, Bargain Purchase, Gain Recognized, Amount	6,387
Common Limited Partners [Member]
Fair value of identifiable assets acquired
Business Combination, Bargain Purchase, Gain Recognized, Amount	14,806
Unaudited Pro Forma Information
Net loss attributable to common unitholders				(50,612)	(24,790)
General Partner [Member]
Fair value of identifiable assets acquired
Business Combination, Bargain Purchase, Gain Recognized, Amount	$ 594
Unaudited Pro Forma Information
Net income				$ (1,911)	(1,084)
Class B Convertible Units [Member] | Class B Convertible Units [Member]
Fair value of identifiable assets acquired
Conversion of Stock, Shares Issued | shares			17,105,875
Southcross Holdings Common [Member]
Unaudited Pro Forma Information
Business Combination, Consideration Transferred					$ 77,640

EARNINGS PER LIMITED PARTNER 48

EARNINGS PER LIMITED PARTNER UNIT AND DISTRIBUTIONS (Details) - USD ($)	3 Months Ended							12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Nov. 14, 2016	May 09, 2016	Dec. 31, 2014
Earnings Per Unit of the Partnership
distributable cash flow ratio								$ 1
Net loss								94,948,000	$ 55,493,000
Net loss attributable to partners								(94,995,000)	(51,399,000)
Net income (loss) allocated to limited partners								$ (94,948,000)	$ (55,493,000)
Basic and diluted net loss per common unit (in dollars per share)								$ (1.48)	$ (0.93)
Class B Convertible Units [Member]
Earnings Per Unit of the Partnership
Distribution made to Member or Limited Partner Distributions Paid in Kind	$ 404,000	$ 0	$ 1,000,000	$ 1,000,000
Preferred Units Cumulative Right to Receive Future Cash Distributions	$ 299,375,000		$ 289,165,000					$ 299,375,000		$ 294,226,000	$ 563,494
Net loss								24,383,000	$ 14,225,000
Series A Preferred Unit in-kind distribution and fair value adjustment									8,059,000
Distributions Made to Member or Limited Partner, Distribution Paid in Kind, Shares		294,226,000	289,165,000	563,494,000
Net income (loss) allocated to limited partners								(24,383,000)	(14,225,000)
Southcross Holdings Common [Member]
Earnings Per Unit of the Partnership
Net loss attributable to partners								$ 0	$ (4,258,000)
General Partner [Member]
Earnings Per Unit of the Partnership
Partners' Capital Account, Units	1,588,198							1,588,198	1,154,965			1,038,852
Distribution made to Member or Limited Partner Distributions Paid in Kind	$ 0	$ 0	$ 0	$ 0
Preferred Units Cumulative Right to Receive Future Cash Distributions	$ 6,109,000	$ 6,004,000	$ 5,901,000					$ 6,109,000
Net loss								1,911,000	$ 1,084,000
Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure								(47,000)	(164,000)
Distributions Made to Member or Limited Partner, Distribution Paid in Kind, Shares		6,004,000	5,901,000	11,499,000
Common Limited Partners [Member]
Earnings Per Unit of the Partnership
Net income (loss) allocated to limited partners								(50,612,000)	(24,790,000)
Interest in net loss								(50,612,000)	(24,790,000)
Dilutive interest in net loss								$ (50,612,000)	$ (24,790,000)
Weighted-average units - basic (in shares)									26,780,825
Weighted-average units - diluted (in shares)									26,780,825
Unvested common units excluded in computation of diluted per-unit amounts (in shares)								19,453	17,168
Subordinated Units
Earnings Per Unit of the Partnership
Net income (loss) allocated to limited partners								$ (18,089,000)	$ (11,300,000)
Interest in net loss								(18,089,000)	(11,300,000)
Dilutive interest in net loss								$ (18,089,000)	$ (11,300,000)
Weighted-average units - basic (in shares)								12,213,713	12,213,713
Weighted-average units - diluted (in shares)								12,213,713	12,213,713
Basic and diluted net loss per subordinated unit (in dollars per share)								$ (1.48)	$ (0.93)
In Kind Distribution [Member] | Class B Convertible Units [Member]
Earnings Per Unit of the Partnership
Distribution made to Member or Limited Partner Distributions Paid in Kind					$ 274,478,000	$ 269,758,000	$ 265,118,000
Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure					1,353,000	2,994,000	3,712,000
In Kind Distribution [Member] | Class B Convertible Units [Member] | General Partner [Member]
Earnings Per Unit of the Partnership
Distribution made to Member or Limited Partner Distributions Paid in Kind					5,601,000	5,505,000	5,410,000
Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure					$ 28,000	$ 61,000	$ 76,000
Cash Distribution [Member]
Earnings Per Unit of the Partnership
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit					$ 0.40	$ 0.40	$ 0.40
Distribution paid in cash					$ 11,827,000	$ 11,782,000	$ 9,938,000
Distribution Made to Member or Limited Partner Unit Distributions Per Unit				$ 0.3257	$ 0.3257	$ 0.3257	$ 0.3257
Cash Distribution [Member] | General Partner [Member]
Earnings Per Unit of the Partnership
Distribution paid in cash					$ 459,000	$ 457,000	$ 418,000
Cash Distribution [Member] | Subordinated Units | Limited Partners [Member]
Earnings Per Unit of the Partnership
Distribution paid in cash					0	0	0
Cash Distribution [Member] | Common Limited Partners [Member] | Limited Partners [Member]
Earnings Per Unit of the Partnership
Distribution paid in cash					$ 11,368,000	$ 11,325,000	$ 9,520,000

EARNINGS PER LIMITED PARTNER 49

EARNINGS PER LIMITED PARTNER UNIT AND DISTRIBUTIONS (Details 2) - USD ($) $ / shares in Units, $ in Thousands	Aug. 04, 2014	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Sep. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Distributions
Aggregate distributions to unitholders											$ 46,915
Class B Convertible Units [Member]
Distributions
Minimum quarterly distribution (in dollars per unit)										$ 0.3257
General Partner [Member]
Distributions
Distributions Made to Member or Limited Partner, Distribution Paid in Kind, Shares			6,004,000	5,901,000	11,499,000
Ownership interest held by general partners (as a percent)	2.00%								2.00%	2.00%
Partners' Capital Account, Units		1,588,198								1,588,198	1,154,965	1,038,852
Distribution made to Member or Limited Partner Distributions Paid in Kind		$ 0	$ 0	$ 0	$ 0
In-kind unit distribution, fair value										$ (47)	$ (164)
Aggregate distributions to unitholders											$ 1,750
Class B Convertible Units [Member]
Distributions
Distributions Made to Member or Limited Partner, Distribution Paid in Kind, Shares			294,226,000	289,165,000	563,494,000
Distribution made to Member or Limited Partner Distributions Paid in Kind		$ 404	$ 0	$ 1,000	$ 1,000
Class B Convertible Units [Member] | Class B Convertible Units [Member]
Distributions
Limited Partner, units outstanding		17,105,875								17,105,875
Conversion of Stock, Shares Issued	17,105,875
Cash Distribution [Member]
Distributions
Distribution Made to Member or Limited Partner Unit Distributions Per Unit					$ 0.3257	$ 0.3257	$ 0.3257	$ 0.3257
Distribution paid in cash						$ 11,827	$ 11,782	$ 9,938
Cash Distribution [Member] | General Partner [Member]
Distributions
Distribution paid in cash						459	457	418
Cash Distribution [Member] | Limited Partners [Member] | Common Units
Distributions
Distribution paid in cash						11,368	11,325	9,520
Maximum [Member] | Cash Distribution [Member]
Distributions
Distribution period		45 days								45 days
Class B Convertible Units [Member] | In Kind Distribution [Member]
Distributions
Distribution made to Member or Limited Partner Distributions Paid in Kind						274,478	269,758	265,118
In-kind unit distribution, fair value						1,353	2,994	3,712
Class B Convertible Units [Member] | In Kind Distribution [Member] | General Partner [Member]
Distributions
Distribution made to Member or Limited Partner Distributions Paid in Kind						5,601	5,505	5,410
In-kind unit distribution, fair value						$ 28	$ 61	$ 76

FINANCIAL INSTRUMENTS (Details)

FINANCIAL INSTRUMENTS (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Fair value of financial instruments
Fair Value of Term Loan	$ 350,000,000
Document Period End Date	Dec. 31, 2016
Interest Rate Cap, 3.00%, $50M	$ 3,759
Derivative, Fair Value, Net	21,319
Interest Rate Derivatives, at Fair Value, Net	(11,000)	$ (159,000)
Derivative Asset	2,000	4,000
Unrealized Gain (Loss) on Derivatives	(147,000)	110,000
Interest Rate Cap $50M, 3% [Member] [Member]
Fair value of financial instruments
Derivative, notional value	40,000,000
Commodity Swaps [Member]
Fair value of financial instruments
Gain (Loss) on Sale of Derivatives	0	214,000
Unrealized Gain (Loss) on Derivatives	0	(111,000)
Interest Rate Swap 1.196% [Member]
Fair value of financial instruments
Derivative, notional value	$ 100,000,000
Derivative, fixed interest rate	1.195%
Interest Rate Cap 3.00% [Member]
Fair value of financial instruments
Derivative, Cap Interest Rate	3.00%
Derivative, Notional Amount, $40M, July1, 2019 Maturity	$ 40,000,000
Derivative, Notional Amount, $50M	50,000,000
Derivative, Notional Amount, $40M, January 1, 2018 Maturity	40,000,000
Derivative, Notional Amount, $40M	80,000,000
Fair Value, Measurements, Recurring [Member] | Interest Rate Cap 3.00% [Member]
Fair value of financial instruments
Interest Rate Cap, 3.00%, $40M, July 1, 2019 Maturity	14,000
Interest Rate Cap 3.00%, $40M, July 1, 2018 Maturity Date	3,000
Interest Rate Cap 3.00%, $40M, January 1, 2018 Maturity	0
Interest Rate Cap, 3.00%, $80M	0
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) | Interest rate swap liability
Fair value of financial instruments
Derivative Asset, Current	2,000	6,000
Fair value measurement	15,000	169,000
Derivatives designated as hedging instruments | Interest rate swap liability
Fair value of financial instruments
Gain (Loss) on Sale of Derivatives	(147,000)
Derivatives designated as hedging instruments | Interest rate cap
Fair value of financial instruments
Gain (Loss) on Sale of Derivatives		(1,000)
Unrealized Gain (Loss) on Derivatives	$ 283,000	$ 416,000

FINANCIAL INSTRUMENTS (Details

FINANCIAL INSTRUMENTS (Details 2) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Derivatives
Commodity swaps, net	$ 21,319
Unrealized loss on interest rate cap	(147,000)	$ 110,000
Interest Rate Cap 1.500% [Member]
Derivatives
Derivative, notional value	$ 20,000,000
Derivative, Cap Interest Rate	1.50%
Interest rate cap contract | Derivatives designated as hedging instruments
Derivatives
Realized gain /(loss) on derivatives		(1,000)
Unrealized loss on interest rate cap	$ 283,000	416,000
Interest rate swap contract | Derivatives designated as hedging instruments
Derivatives
Realized gain /(loss) on derivatives	(147,000)
Commodity Swaps
Derivatives
Realized gain /(loss) on derivatives	0	214,000
Unrealized loss on interest rate cap	0	$ (111,000)
Interest Rate Swap 1.196% [Member]
Derivatives
Derivative, notional value	$ 100,000,000
Derivative, fixed interest rate	1.195%
Interest Rate Cap $50M, 3% [Member] [Member]
Derivatives
Derivative, notional value	$ 50,000,000
Derivative, Cap Interest Rate	3.00%
Fair Value, Measurements, Recurring [Member] | Interest Rate Cap 1.500% [Member]
Derivatives
Derivative Liability, Fair Value, Gross Asset	$ 0

LONG-LIVED ASSETS (Details)

LONG-LIVED ASSETS (Details) - USD ($) $ / shares in Units, $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Unusual or Infrequent Item, Earnings Per Share Impact, Gross		$ 0.51
Expected useful lives of contracts		30 years
Accumulated depreciation and amortization		$ (262,709)	$ (212,991)
Depreciation		32,500
Property, plant and equipment
Property, plant and equipment, net		971,286	1,066,001
Depreciation expense		106,947	70,814
Proceeds from Sale of Productive Assets		22,470	4,693
Intangible assets, net		1,400	1,500
Property, Plant and Equipment [Member] | Property, Plant and Equipment [Member]
Property, plant and equipment
Total property, plant and equipment		1,195,414	1,221,179
Property Plant Equipment Excluding Construction in Progress Land and Other [Member] | Property Plant Equipment Excluding Construction in Progress Land and Other [Member]
Property, plant and equipment
Property, plant and equipment, net		932,705	1,008,188
Land [Member] | Land [Member]
Property, plant and equipment
Property, plant and equipment, net		22,431	25,599
Construction in Progress [Member] | Construction in Progress [Member]
Property, plant and equipment
Property, plant and equipment, net		$ 16,150	$ 32,214
Vehicles [Member] | Vehicles [Member]
Property, plant and equipment
Property, Plant and Equipment, Useful Life		3 years	5 years
Total property, plant and equipment		$ 1,713	$ 2,442
Furniture and Fixtures [Member] | Furniture and Fixtures [Member]
Property, plant and equipment
Total property, plant and equipment		9,269	9,252
Right of Way [Member] | Right of Way [Member]
Property, plant and equipment
Total property, plant and equipment		$ 49,998	$ 46,692
Compressor [Member] | Compressor [Member]
Property, plant and equipment
Property, Plant and Equipment, Useful Life		5 years	15 years
Total property, plant and equipment		$ 72,054	$ 72,750
Natural Gas Processing Plant [Member] | Natural Gas Processing Plant [Member]
Property, plant and equipment
Total property, plant and equipment		$ 509,840	$ 547,253
Pipelines [Member] | Pipelines [Member]
Property, plant and equipment
Property, Plant and Equipment, Useful Life		15 years	30 years
Total property, plant and equipment		$ 552,540	$ 542,790
Formosa Pipeline [Member]
Property, plant and equipment
Gain (Loss) on Sale of Assets and Asset Impairment Charges	$ (13,600)
Proceeds from Sale of Productive Assets	$ 15,000
Insurance Settlement [Member]
Property, plant and equipment
Increase (Decrease) in Insurance Settlements Receivable		$ 2,000

LONG-TERM DEBT (Details)

LONG-TERM DEBT (Details)	Aug. 04, 2014USD ($)	Dec. 31, 2016USD ($)	Sep. 30, 2016	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Jun. 30, 2016USD ($)	Dec. 31, 2014USD ($)	Apr. 12, 2013USD ($)
LONG TERM DEBT
Long Term Debt, Gross				$ 561,305,000
Senior Notes, Current						$ 300,000
Consolidated Total Leverage Ratio			5
Cost of Goods and Services Sold, Depreciation and Amortization				106,947,000	$ 70,814,000
Deferred Finance Costs, Net		$ (11,474,000)		(11,474,000)	(14,141,000)		$ (16,602,000)
Long-term Debt		559,846,000		559,846,000	623,159,000
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months		4,500,000		4,500,000
Long-term Debt, Maturities, Repayments of Principal in Rolling Year Two and Three		4,500,000		4,500,000
Long-term Debt, Maturities, Repayments of Principal in Year Three		127,055,000		127,055,000
Long-term Debt, Maturities, Repayments of Principal in Year Four		4,500,000		4,500,000
Long-term Debt, Maturities, Repayments of Principal in Rolling Year Four and Five		420,750,000		$ 420,750,000
Debt Instrument, Term				5 years
Long-term Line of Credit		200,000,000		$ 200,000,000
Reduction in total aggregate commitments		145,000,000
Other Long-term Debt		437,291,000		437,291,000	441,464,000
Total long-term debt		543,872,200		543,872,200	604,518,000
Average borrowings outstanding				591,970,000	564,568,000
Maximum outstanding borrowings				628,055,000	624,945,000
Sublimit for letters of credit reduction		$ 50,000,000
Reduction in total aggregate commitments, September 30, 2017				140,000,000
Reduction in total aggregate commitments, December 31, 2017				135,000,000
Reduction in total aggregate commitments, March 31, 2018				125,000,000
Reduction in total aggregate commitments, June 30, 2018				120,000,000
Reduction in total aggregate commitments, December 31, 2018				115,000,000
Consolidated Total Leverage Ratio, is greater than or equal to 5.00 to 1.00				5
Consolidated Total Leverage Ratio, is greater than or equal to 6.00 to 1.00				6
Consolidated Total Leverage Ratio, is greater than or equal to 7.00 to 1.00				7
Consolidated Total Leverage Ratio, is greater than or equal to 8.00 to 1.00				8
Consolidated Total Leverage Ratio, is greater than or equal to 8.00 to 1.00, that is payable in kind				$ 8
Consolidated Interest Coverage Ratio				2.50
Consolidated interest coverage ratio amendment		1.50
Minimum liquidity requirement		$ 3,000,000
Leverage ratio				5
Excess cash flow				50.00%
Cash distribution restriction				$ 10,000,000
Consolidated Senior Secured Leverage Ratio				3.50
Loss on extinguishment of debt				$ (1,006,000)	0
Proceeds from Issuance of Other Long-term Debt	$ 450,000,000
Line of Credit Facility, Interest Rate Description	0.01
Amortization of Debt Discount (Premium)	$ 0.01
Debt Instrument, Periodic Payment	$ 1,125,000
Allowable Number of Quarterly Equity Cures				two in a twelve
Third A&R Credit Agreement, total revolving credit exposure		145,200,000
Third A&R Revolving Credit Agreement, excess cash balance		15,000,000
Capitalization of deferred financing costs				$ 1,366,000	698,000
Write-off of deferred financing costs, Revolver Term Loan				(1,006,000)	0
Amortization of Financing Costs					(3,159,000)
Long-term Debt, Current Maturities		(4,500,000)		(4,500,000)	(4,500,000)
General Partner [Member]
LONG TERM DEBT
Long-term Line of Credit		19,378,000		19,378,000	18,305,000
Credit Facility, due November 2017 [Member]
LONG TERM DEBT
Long-term Debt		122,555,000		122,555,000	181,695,000
Line of Credit Facility, Remaining Borrowing Capacity		$ 3,067,000		$ 3,067,000	$ 0
Basis spread on variable rate (as a percent)	4.25%
Leverage ratio		5		5.3
Credit Facility, due November 2017 [Member] | Credit Agreement Covenant September 30 2013 [Member]
LONG TERM DEBT
Debt Instrument, Interest Rate During Period				5.25%	5.16%
Letter of Credit [Member]
LONG TERM DEBT
Maximum borrowing capacity	$ 75,000,000	$ 200,000,000		$ 200,000,000				$ 75,000,000
Eurodollar [Member]
LONG TERM DEBT
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum				2.00%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum				4.50%
Minimum Commitment Fee [Member]
LONG TERM DEBT
Line of Credit Facility, Commitment Fee Percentage				0.375%
Maximum Commitment Fee [Member]
LONG TERM DEBT
Line of Credit Facility, Commitment Fee Percentage				0.50%

COMMITMENTS AND CONTINGENT LI54

COMMITMENTS AND CONTINGENT LIABILITIES (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Long-term Purchase Commitment [Line Items]
Amount Received on Formosa Settlement	$ 1,600
Receivable Recorded on Formosa Settlement	1,600
Formosa Settlement	3,100
Legal Matters
Amortization expense related to capital leases	400	$ 500
Future minimum annual rental commitments under capital leases
Operating Leases, Future Minimum Payments, Due Thereafter	19,492
Capital Lease Obligations Incurred	387	378
Future minimum annual rental commitments under our operating leases
2,014	3,634
2,015	3,477
2,016	3,409
2,017	2,912
2,018	1,148
Total	4,912
Expenses associated with operating leases
Expenses associated with operating leases	$ 5,800	5,300
Deferred Rent Credit		$ 2,300

COMMITMENTS AND CONTINGENT LI55

COMMITMENTS AND CONTINGENT LIABILITIES (Details 2) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Long-term Purchase Commitment [Line Items]
Capital Leases, Income Statement, Amortization Expense	$ 0.4	$ 0.5
Operating Leases, Rent Expense, Net	$ 5.8	$ 5.3
Document Period End Date	Dec. 31, 2016

TRANSACTIONS WITH RELATED PAR56

TRANSACTIONS WITH RELATED PARTIES (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2016	Dec. 31, 2015
Related Party Transaction [Line Items]
PIK Note Interest Rate	7.00%
Charlesbank Ownership of Holdings			one-third
NGL purchases from Holdings			$ 10,000
Document Period End Date			Dec. 31, 2016
Accounts Receivable, Related Parties			$ 7,976	$ 49,734
Related Party Transaction Reimbursement Expenses from Transactions with Related Party			4,053	1,023
Revenue from Related Parties			97,500	94,700
Due to Affiliate, Current			(524)	(7,871)
Operating Costs and Expenses			1,700
Affiliate Costs			0	17,858
office move costs allocated to Holdings			2,320	2,320
Restructuring Bonus Percentage	100.00%
Accrued Bonuses, Current	$ 1,500
Southcross Energy LLC [Member]
Related Party Transaction [Line Items]
compensation expense allocated to Southcross Energy			600
valley wells [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties				7,049
Affiliate Costs				2,670
valley wells [Member] | Common Units
Related Party Transaction [Line Items]
Affiliate Costs	$ 1,400	$ 1,000	$ 2,406	$ 2,670

SERIES A CONVERTIBLE PREFERRE57

SERIES A CONVERTIBLE PREFERRED UNITS SERIES A CONVERTIBLE PREFERRED UNITS (Details)	Apr. 12, 2013
General Partner [Member]
Capital Unit [Line Items]
Ownership interest held by limited partners (as a percent)	2.00%

PARTNERS' CAPITAL AND MEMBERS58

PARTNERS' CAPITAL AND MEMBERS' EQUITY (Details)	May 07, 2015USD ($)	Aug. 04, 2014shares	Apr. 12, 2013	Dec. 31, 2016USD ($)$ / sharesshares	Sep. 30, 2016USD ($)shares	Jun. 30, 2016USD ($)shares	Mar. 31, 2016USD ($)shares	Sep. 30, 2015$ / sharesshares	Jun. 30, 2015$ / sharesshares	Mar. 31, 2015$ / shares	Sep. 30, 2016USD ($)	Dec. 31, 2016USD ($)$ / sharesshares	Dec. 31, 2015USD ($)shares	Nov. 14, 2016USD ($)	May 09, 2016USD ($)	Dec. 31, 2014shares	Sep. 30, 2014$ / shares
Limited Partners' Capital Account [Line Items]
Cost of Goods and Services Sold, Depreciation and Amortization | $												$ 106,947,000	$ 70,814,000
Document Period End Date												Dec. 31, 2016
Stock Issued During Period, Shares, New Issues						359,459,000	8,029,729,000
Equity Cure | $						$ 500,000	$ 11,900,000
Holdings common units received for capital commitment				11,486,486,000,000
Preferred Stock, Participation Rights												1
Capital contribution | $													$ 1,301,000
Ownership Interest Percentage of Parent in Consolidated Subsidiaries				100.00%								100.00%
Share-based Compensation Arrangement by Share-based Payment Award, Accelerated Vesting, Number												84,423
Payments to Acquire Businesses, Gross | $	$ 77,600,000
Payments to Acquire Businesses, Net of Cash Acquired | $	$ 15,000,000
Subordinated Units [Member]
Limited Partners' Capital Account [Line Items]
Preferred Stock, Shares Outstanding				12,213,713								12,213,713	12,213,713			12,213,713
Common Unit, Issued				0								0
Stock Issued During Period, Shares, Share-based Compensation, Gross													0
Share-based Compensation Arrangement by Share-based Payment Award, Accelerated Vesting, Number												0	0
Distribution Made to Limited Partner, Unit Distribution												0	0
General Partner [Member]
Limited Partners' Capital Account [Line Items]
Preferred Units Cumulative Right to Receive Future Cash Distributions | $				$ 6,109,000	$ 6,004,000	$ 5,901,000					$ 6,004,000	$ 6,109,000
Common Unit, Issued				0								0
Stock Issued During Period, Shares, New Issues					234,419,000	171,209,000
Ownership interest held by limited partners (as a percent)			2.00%
Stock Issued During Period, Shares, Share-based Compensation, Gross													0
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest		2.00%									2.00%	2.00%
Capital contribution | $													$ 1,301,000
Partners' Capital Account, Units				1,588,198								1,588,198	1,154,965			1,038,852
Share-based Compensation Arrangement by Share-based Payment Award, Accelerated Vesting, Number												0	0
Distribution Made to Limited Partner, Unit Distribution												433,233	116,113
Common Units
Limited Partners' Capital Account [Line Items]
Common Unit, Issued				0								0
Stock Issued During Period, Shares, Share-based Compensation, Gross													17,185
Common units outstanding				22,010,016								22,010,016	21,804,219			21,684,543
Share-based Compensation Arrangement by Share-based Payment Award, Accelerated Vesting, Number													102,491
Distribution Made to Limited Partner, Unit Distribution												0	0
Class B Convertible Units [Member]
Limited Partners' Capital Account [Line Items]
Preferred Units Cumulative Right to Receive Future Cash Distributions | $				$ 299,375,000		$ 289,165,000						$ 299,375,000		$ 294,226,000	$ 563,494
Preferred Stock, Shares Outstanding				17,105,875								17,105,875	15,958,990			14,889,078
Common Unit, Issued				0								0
Stock Issued During Period, Shares, Share-based Compensation, Gross													0
Share-based Compensation Arrangement by Share-based Payment Award, Accelerated Vesting, Number												0	0
Distribution Made to Limited Partner, Unit Distribution												1,146,885	1,069,912
Southcross Holdings Common [Member]
Limited Partners' Capital Account [Line Items]
Stock Issued During Period, Shares, Share-based Compensation, Gross													0
Common units outstanding				26,492,074								26,492,074	6,616,400			2,116,400
Partners' Capital Account, Units, Acquisitions													4,500,000
Share-based Compensation Arrangement by Share-based Payment Award, Accelerated Vesting, Number												0	0
Distribution Made to Limited Partner, Unit Distribution												0	0
Common Units [Member]
Limited Partners' Capital Account [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest		55.00%
Common Stock, Shares, Issued								4,500,000	4,500,000
Limited Partners [Member]
Limited Partners' Capital Account [Line Items]
Stock Issued During Period, Shares, New Issues												19,875,674
Redeemable
Limited Partners' Capital Account [Line Items]
Series A convertible preferred units issued													14,889,078			1,769,915
Class B Convertible Units [Member]
Limited Partners' Capital Account [Line Items]
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit | $ / shares				$ 0.3257								$ 0.44
Cash purchase price (in dollars per unit) | $ / shares																	$ 18.61
Distribution Made to Limited Partner, Distributions Paid, Per Unit | $ / shares												$ 0.3257
Class B Convertible Units [Member] | Class B Convertible Units [Member]
Limited Partners' Capital Account [Line Items]
Conversion of Stock, Shares Issued		17,105,875
Cash Distribution [Member]
Limited Partners' Capital Account [Line Items]
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit | $ / shares								$ 0.40	$ 0.40	$ 0.40
Cash Distribution [Member] | Maximum [Member]
Limited Partners' Capital Account [Line Items]
Distribution Made to Member or Limited Partner Distribution Period				45 days								45 days

INCENTIVE COMPENSATION (Details

INCENTIVE COMPENSATION (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Sep. 30, 2016	Sep. 30, 2014
Unit based compensation
Shared-based Compensation Arrangement by Share-based Payment Award, Equity Instruments, Vested, Weighted-Average Fair Value Vesting Date		$ 9.17	$ 1.57
Shared-based Compensation Arrangement by Share-based Payment Award, Equity Instruments, Recaptured for Tax Withholding, Vested, Weighted-Average Fair Value Vesting Date		8.41	$ 1.52
Document Period End Date	Dec. 31, 2016
Units
Granted units (in shares)	47,500
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Intrinsic Value, Amount Per Share	$ 3.56
Forfeited units (in shares)	(73,493)
Weighted-average grant date fair value
Forfeited units (in dollars per unit)	$ 15.35	$ 18.79
Units recaptured for tax withholdings (in dollars per unit)	$ 16.42
Share-based Compensation Arrangement by Share-based Payment Award, Accelerated Vesting, Number	84,423
Unit-based compensation expense	$ 3,523,000	$ 4,573,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Nonvested Options Forfeited, Number of Shares		(204,530)
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period	10
Shares Paid for Tax Withholding for Share Based Compensation	(87,849)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Number	(205,797)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Exercise Price	$ 15.92
Phantom Units
Units
Vested units (in shares)		(125,041)
Weighted-average grant date fair value
Vested units (in dollars per share)		$ 10.36
Incentive Plan
Units
Unvested at the beginning of the period (in shares)	687,920	470,750
Granted units (in shares)		594,333
Units recaptured for tax withholdings (in shares)		47,592
Unvested at the end of the period (in shares)		687,920
Weighted-average grant date fair value
Unvested at the beginning of the period (in dollars per unit)	$ 15.56	$ 20.45
Granted units (in dollars per unit)		11.82
Units recaptured for tax withholdings (in dollars per unit)		8.41
Unvested at the end of the period (in dollars per unit)		$ 15.56
Fair value	$ 200,000	$ 7,000,000
Unamortized compensation expense	$ 3,100,000	$ 7,600,000
Units available for issuance (in shares)	5,171,916	5,058,073
Long Term Incentive Plan [Member]
Units
Unvested at the end of the period (in shares)	368,281
Weighted-average grant date fair value
Unvested at the end of the period (in dollars per unit)	$ 14.91
Long Term Incentive Phantom Units approved	4,500,000
Employee Savings Plan
Weighted-average grant date fair value
Defined Contribution Plan, Employer Matching Contribution, Percent of Employee's Contribution	100.00%
Employer matching contribution, percent of employees' gross pay	6.00%
Maximum annual contributions by employer, amount	$ 15,900
Matching contributions expensed for employee savings plan	$ 1,252,000	$ 709,000
Class B Convertible Units [Member]
Unit based compensation
Share price				$ 18.61
3yr vesting period [Member] | Incentive Plan
Weighted-average grant date fair value
Period of amortization of compensation expense	3 years
1yr vesting period [Member] | Incentive Plan
Weighted-average grant date fair value
1yr vesting period	1

REVENUES (Details)

REVENUES (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Revenues [Abstract]
Sales of natural gas	$ 271,302	$ 399,828
Sales of NGLs and condensate	158,968	154,478
Transportation, gathering and processing fees	113,482	138,717
Other	4,971	5,450
Revenues:	$ 548,723	$ 698,473

EQUITY IN JOINT VENTURES (Detai

EQUITY IN JOINT VENTURES (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)segment	Dec. 31, 2015USD ($)	Aug. 04, 2014
Business Acquisition [Line Items]
Equity Method Investment Summarized Financial Information, Equity	$ 124,096	$ 140,526
Income (Loss) from Equity Method Investments	(21,123)	(13,452)
Revenues:	$ 548,723	698,473
number of joint ventures | segment	3
Property, plant and equipment, net	$ 971,286	1,066,001
Assets	1,186,076	1,318,960
Liabilities	622,447
Liabilities and Equity	1,186,076
Net Income (Loss) Attributable to Parent	(94,948)	(55,493)
T2 Eagle Ford [Member]
Business Acquisition [Line Items]
Property, plant and equipment, net	203,810	217,370
Assets	206,327	221,895
Liabilities	2,173	9,697
Members' Equity	204,154	212,198
Liabilities and Equity	206,327	221,895
Equity Method Investment, Ownership Percentage			50.00%
Assets, Current	2,517	4,525
T2 Cogen [Member]
Business Acquisition [Line Items]
Property, plant and equipment, net	12,000	32,333
Assets	12,603	34,319
Liabilities	596	824
Members' Equity	12,006	33,495
Liabilities and Equity	12,603	34,319
Equity Method Investment, Ownership Percentage			50.00%
Assets, Current	603	1,986
T2 LaSalle [Member]
Business Acquisition [Line Items]
Property, plant and equipment, net	66,028	71,491
Assets	67,074	72,719
Liabilities	1,262	622
Members' Equity	65,812	72,097
Liabilities and Equity	67,074	72,719
Equity Method Investment, Ownership Percentage			25.00%
Assets, Current	1,046	1,228
T2 Cogen [Member]
Business Acquisition [Line Items]
Equity Method Investment Summarized Financial Information, Equity	6,003	16,747
Income (Loss) from Equity Method Investments	(9,999)	(2,919)
Revenues:	2,556	2,437
Net Income (Loss) Attributable to Parent	(19,998)	(5,837)
T2 Eagle Ford [Member]
Business Acquisition [Line Items]
Equity Method Investment Summarized Financial Information, Equity	101,669	105,755
Income (Loss) from Equity Method Investments	(9,656)	(9,068)
Revenues:	5,667	6,850
Net Income (Loss) Attributable to Parent	(19,312)	(18,802)
T2 LaSalle [Member]
Business Acquisition [Line Items]
Equity Method Investment Summarized Financial Information, Equity	16,424	18,024
Income (Loss) from Equity Method Investments	(1,468)	(1,465)
Revenues:	1,963	1,297
Net Income (Loss) Attributable to Parent	$ (5,872)	$ (5,860)

CONCENTRATION OF CREDIT RISK 62

CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Consolidated revenue concentration
Concentration risk percentage	10.00%
Allowance for Accounts Receivable	no
Allowance for Doubtful Accounts Receivable, Current		$ 100,000	$ 0
Trafigura AG [Member] | Customer concentration | Consolidated revenue
Consolidated revenue concentration
Concentration risk percentage	10.70%
Top ten customers | Customer concentration | Consolidated revenue
Consolidated revenue concentration
Concentration risk percentage	53.50%	54.20%

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - USD ($) $ / shares in Units, $ in Millions	Apr. 12, 2013	Dec. 31, 2016	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015
Subsequent events
Other Additional Capital							$ 50
Class B Convertible Units [Member]
Subsequent events
Minimum quarterly distribution (in dollars per unit)		$ 0.3257				$ 0.44
General Partner [Member]
Subsequent events
Ownership interest held by limited partners (as a percent)	2.00%
Cash Distribution [Member]
Subsequent events
Minimum quarterly distribution (in dollars per unit)			$ 0.40	$ 0.40	$ 0.40

SUBSEQUENT EVENTS (Details 2)

SUBSEQUENT EVENTS (Details 2)	May 07, 2015USD ($)	Aug. 04, 2014USD ($)	Apr. 12, 2013USD ($)	Dec. 31, 2016USD ($)$ / shares	Mar. 31, 2016$ / shares	Sep. 30, 2015$ / shares	Jun. 30, 2015$ / shares	Mar. 31, 2015$ / shares	Sep. 30, 2016	Dec. 31, 2016USD ($)$ / shares
Subsequent events
Leverage ratio										5
Payments to Acquire Businesses, Gross | $	$ 77,600,000
Payments to Acquire Businesses, Net of Cash Acquired | $	$ 15,000,000
General Partner Units [Member]
Subsequent events
Ownership interest held by limited partners (as a percent)			2.00%
Ownership interest held by general partners (as a percent)		2.00%							2.00%	2.00%
Cash
Subsequent events
Distribution Made to Member or Limited Partner Unit Distributions Per Unit | $ / shares					$ 0.3257	$ 0.3257	$ 0.3257	$ 0.3257
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit | $ / shares						$ 0.40	$ 0.40	$ 0.40
Maximum [Member] | Cash
Subsequent events
Distribution Made to Member or Limited Partner Distribution Period				45 days						45 days
Class B Convertible Units [Member]
Subsequent events
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit | $ / shares				$ 0.3257						$ 0.44
Senior Secured Credit Facility [Member]
Subsequent events
Leverage ratio				5						5.3
Letter of Credit [Member]
Subsequent events
Line of Credit Facility, Maximum Borrowing Capacity | $		$ 75,000,000	$ 75,000,000	$ 200,000,000						$ 200,000,000
Eurodollar [Member]
Subsequent events
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum										2.00%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum										4.50%
Base Rate [Member]
Subsequent events
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum										1.00%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum										3.50%
Minimum Commitment Fee [Member]
Subsequent events
Line of Credit Facility, Commitment Fee Percentage										0.375%
Maximum Commitment Fee [Member]
Subsequent events
Line of Credit Facility, Commitment Fee Percentage										0.50%

SUPPLEMENTAL CASH FLOW INFORM65

SUPPLEMENTAL CASH FLOW INFORMATION (Details) - USD ($) $ in Thousands	May 08, 2015	Dec. 31, 2016	Dec. 31, 2015	Sep. 30, 2016
Restructuring Cost and Reserve [Line Items]
Capital Lease Obligations Incurred		$ 387	$ 378
Noncash Financing Activities, Accrued Distribution on Long Term Incentive Plan			689
Accounts payable related to capital expenditures			5,773
Cash paid for interest			32,293
Business Combination, Consideration Transferred			15,000
Deferred Revenue, Revenue Recognized		2,600	2,600
Business Combination, Pro Forma Information, Revenue of Acquiree since Acquisition Date, Actual		3,000	3,000
2,015		3,477
2,016		3,409
2,017		2,912
2,018		1,148
Operating Leases, Future Minimum Payments, Due Thereafter		19,492
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities			1,436
Interest Costs Capitalized Adjustment		(36,066)	(34,517)
Interest Expense		(900)	(1,779)
office move costs allocated to Holdings		2,320	2,320
Paid-in-Kind Interest		260	0
Deferred Revenue		8,500	5,500
Natural Gas Pipeline Contracts [Member]
Restructuring Cost and Reserve [Line Items]
Operating Leases, Future Minimum Payments Receivable, in Two Years				$ 5,600
2,016				2,200
2,017				2,200
2,018				2,200
Operating Leases, Future Minimum Payments, Due Thereafter				$ 13,100
valley wells [Member]
Restructuring Cost and Reserve [Line Items]
Business Combination, Bargain Purchase, Gain Recognized, Amount	$ 29,716
Class B Convertible Units [Member]
Restructuring Cost and Reserve [Line Items]
Series A Preferred fair value adjustment			0
Southcross Holdings Common [Member]
Restructuring Cost and Reserve [Line Items]
Business Combination, Consideration Transferred			77,640
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities			1,436
Common Units
Restructuring Cost and Reserve [Line Items]
Business Combination, Bargain Purchase, Gain Recognized, Amount	14,806
Payments to Acquire Interest in Subsidiaries and Affiliates			62,640
Common Units | valley wells [Member]
Restructuring Cost and Reserve [Line Items]
Affiliate Costs			1,647
Common Units | Class B Convertible Units [Member]
Restructuring Cost and Reserve [Line Items]
Series A Preferred fair value adjustment		1,654	(5,340)
Class B Convertible Units [Member]
Restructuring Cost and Reserve [Line Items]
Series A Preferred fair value adjustment			8,059
Business Combination, Bargain Purchase, Gain Recognized, Amount	$ 7,929
Class B Convertible Units [Member] | Class B Convertible Units [Member]
Restructuring Cost and Reserve [Line Items]
Series A Preferred fair value adjustment		$ (2,307)	$ 8,059

SUPPLEMENTAL SELECTED QUARTERLY

SUPPLEMENTAL SELECTED QUARTERLY FINANCIAL INFORMATION (UNAUDITED) SUPPLEMENTAL SELECTED QUARTERLY FINANCIAL INFORMATION (UNAUDITED) (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Revenues:	$ 548,723	$ 698,473
Net loss	(94,948)	(55,493)
Payments of distributions and distribution equivalent rights	$ 0	$ 46,915
Basic and diluted net loss per subordinated unit (in dollars per share)	$ (1.48)	$ (0.93)
General Partner [Member]
Condensed Financial Statements, Captions [Line Items]
Net loss	$ (1,911)	$ (1,084)

Uncategorized Items - sxe-20161

Label	Element	Value
2015 Holdings Acquisition [Member] | Southcross Holdings Common [Member]
Business Combination, Bargain Purchase, Gain Recognized, Amount	us-gaap_BusinessCombinationBargainPurchaseGainRecognizedAmount	$ 29,716,000