Southcross Energy Partners 10-Q 7 Aug 15 2015 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	Aug. 07, 2015	Aug. 04, 2014	Jun. 30, 2015	Dec. 31, 2014
Entity Registrant Name			Southcross Energy Partners, L.P.
Entity Central Index Key			1,547,638
Document Type			10-Q
Document Period End Date			Jun. 30, 2015
Amendment Flag			false
Current Fiscal Year End Date			--12-31
Entity Current Reporting Status			Yes
Entity Filer Category			Accelerated Filer
Entity Common Stock, Shares Outstanding	28,311,673
Document Fiscal Year Focus			2,015
Document Fiscal Period Focus			Q2
Class B Convertible Units [Member] | Class B Convertible Units [Member]
Conversion of Stock, Shares Issued		14,633,000
Limited Partner, units authorized
Limited Partner, units authorized			25,179,351	13,963,713
Common Stock, Shares, Outstanding			21,695,273	21,684,543
Subsequent Event [Member] | Class B Convertible Units [Member] | Class B Convertible Units [Member]
Weighted Average Number of Shares Outstanding, Basic	15,414,754

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($)	Jun. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 8,217,000	$ 1,649,000
Trade accounts receivable	45,323,000	74,086,000
Accounts Receivable, Related Parties	19,779,000	11,325,000
Prepaid expenses	1,706,000	3,073,000
Other current assets	846,000	1,813,000
Total current assets	75,871,000	91,946,000
Property, plant and equipment, net	1,087,497,000	1,058,570,000
Intangible assets, net	1,483,000	1,511,000
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	142,197,000	147,098,000
Other assets	16,152,000	17,189,000
Total assets	1,323,200,000	1,316,314,000
Current liabilities:
Accounts payable and accrued liabilities	68,023,000	116,842,000
Due to Affiliate, Current	14,294,000	12,856,000
Other Long-term Debt, Current	4,500,000	4,500,000
Other current liabilities	11,123,000	12,773,000
Total current liabilities	97,940,000	146,971,000
Long-term debt	556,049,000	471,129,000
Other non-current liabilities	2,523,000	1,110,000
Total liabilities	656,512,000	619,210,000
Partners' capital:
Accumulated Other Comprehensive Income (Loss), Net of Tax	0	77,320,000
Total partners' capital	666,688,000	697,104,000
Liabilities, preferred units, and partners' capital:
Total liabilities, preferred units and partners' capital	1,323,200,000	1,316,314,000
Limited Partner, units authorized
Partners' capital:
Total partners' capital	303,876,000	259,735,000
Class B Convertible Units [Member]
Partners' capital:
Total partners' capital	306,167,000	298,833,000
Subordinated Units [Member]
Partners' capital:
Total partners' capital	43,733,000	48,831,000
General Partner interest [Member]
Partners' capital:
General Partner interest	12,912,000	12,385,000
Total partners' capital	$ 12,912,000	$ 12,385,000

CONDENSED CONSOLIDATED BALANCE3

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Jun. 30, 2015	Dec. 31, 2014	Aug. 04, 2014
Limited Partner, units authorized
Partners' capital:
Limited Partner, units authorized	25,179,351	13,963,713
Limited Partner, units outstanding	21,454,119	12,253,985
Subordinated Units [Member]
Partners' capital:
Limited Partner, units authorized	12,213,713		12,213,713
Limited Partner, units issued		12,213,713
Limited Partner, units outstanding	12,213,713	12,213,713

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues	$ 146,129,000	$ 195,063,000	$ 324,620,000	$ 408,654,000
Total revenues	167,220,000	195,063,000	353,158,000	408,654,000
Revenue from Related Parties	21,091,000	0	28,538,000	0
Expenses:
Cost of natural gas and liquids sold	124,595,000	168,826,000	265,710,000	355,229,000
Operations and maintenance	19,834,000	11,745,000	42,388,000	22,606,000
Depreciation and amortization	17,571,000	8,978,000	34,603,000	17,506,000
General and administrative	9,003,000	6,693,000	16,809,000	12,796,000
Asset Impairment Charges	193,000	0	193,000	0
Loss (gain) on sale of assets, net	(38,000)	(45,000)	180,000	(42,000)
Total expenses	171,158,000	196,197,000	359,883,000	408,095,000
Income (loss) from operations	(3,938,000)	(1,134,000)	(6,725,000)	559,000
Income (Loss) from Equity Method Investments	(3,604,000)		(7,155,000)
Interest expense	(7,900,000)	(1,771,000)	(15,398,000)	(4,744,000)
Other Cost and Expense, Operating	11,504,000	1,771,000	22,553,000	4,744,000
Loss before income tax expense	(15,442,000)	(2,905,000)	(29,278,000)	(4,185,000)
Interest expense	(9,000)	(56,000)	(78,000)	(64,000)
Net loss	(15,451,000)	(2,961,000)	(29,356,000)	(4,249,000)
Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure				0
General partner Unit in-kind distribution	(61,000)
Net loss attributable to partners	$ (14,409,000)	(8,761,000)	(25,235,000)	(10,550,000)
Earnings per unit and distributions declared
Net loss allocated to limited partner, basic and diluted			(29,356,000)	(4,249,000)
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit	$ 0.40
General Partner [Member]
Expenses:
Net loss	$ (306,000)	(59,000)	(561,000)
Net Income (Loss) Allocated to General Partners			(502,000)	(84,000)
Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure	(61,000)	0	(137,000)
Earnings per unit and distributions declared
Net loss allocated to limited partner, basic and diluted				(85,000)
Southcross Holdings Common [Member]
Expenses:
Net loss attributable to partners	(1,103,000)	0	(4,258,000)	0
Class B Convertible Units [Member]
Expenses:
Net loss	(3,981,000)		(7,100,000)
Earnings per unit and distributions declared
Net loss allocated to limited partner, basic and diluted			(7,100,000)
Limited Partners
Expenses:
Net loss attributable to partners			(25,235,000)
Common Limited Partners [Member]
Earnings per unit and distributions declared
Net loss allocated to limited partner, basic and diluted	$ (6,928,000)	$ (7,382,000)	$ (11,830,000)	$ (8,398,000)
Weighted average number of limited partner units outstanding, basic and diluted	26,477	21,472	25,143	19,888
Basic and diluted loss per unit (in dollars per unit)	$ (0.26)	$ (0.34)	$ (0.47)	$ (0.42)
Subordinated Limited Partners [Member]
Earnings per unit and distributions declared
Net loss allocated to limited partner, basic and diluted	$ (3,194,000)	$ (1,320,000)	$ (5,744,000)	$ (2,068,000)
Weighted average number of limited partner units outstanding, basic and diluted	12,214	12,214	12,214	12,214
Basic and diluted loss per unit (in dollars per unit)	$ (0.26)	$ (0.11)	$ (0.47)	$ (0.17)
Preferred units issued
Expenses:
Dividends, Preferred Stock, Paid-in-kind	$ 0	$ 738,000	$ 0	$ 1,272,000
Earnings per unit and distributions declared
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit			$ 0.40
Cash Distribution [Member]
Earnings per unit and distributions declared
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit	$ 0.4	$ 0.4
Distribution Made to Member or Limited Partner, Distribution Paid in Cash	$ 11,782,000	$ 14,575,000
Cash Distribution [Member] | General Partner [Member]
Earnings per unit and distributions declared
Distribution Made to Member or Limited Partner, Distribution Paid in Cash	$ 457,000	$ 290,000
Cash Distribution [Member] | Subordinated Limited Partners [Member] | Limited Partners
Earnings per unit and distributions declared
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit	$ 0.40	$ 0.40
Distribution Made to Member or Limited Partner, Distribution Paid in Cash	$ 0	$ 4,886,000	$ 0	$ 0
Cash Distribution [Member] | Common Limited Partners [Member] | Limited Partners
Earnings per unit and distributions declared
Distribution Made to Member or Limited Partner, Distribution Paid in Cash	$ 11,325,000	$ 9,399,000

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Statement of Comprehensive Income [Abstract]
Net loss	$ (15,451)	$ (2,961)	$ (29,356)	$ (4,249)
Other comprehensive income (loss):
Hedging losses reclassified to earnings and recognized in interest expense	0	106	0	221
Adjustment in fair value of derivatives	0	0	0	(11)
Total other comprehensive income	0	106	0	210
Comprehensive loss	$ (15,451)	$ (2,855)	$ (29,356)	$ (4,039)

CONDENSED CONSOLIDATED STATEME6

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Net Cash Provided by (Used in) Financing Activities, Continuing Operations	$ 79,705	$ 79,310
Net cash used in investing activities	(77,640)	(95,452)
Cash and cash equivalents	8,217	10,908
Cash flows from operating activities:
Net loss	(29,356)	(4,249)
Depreciation and amortization	34,603	17,506
Unit-based compensation	2,475	1,611
Amortization of deferred financing costs	1,727	675
Loss (gain) on sale of assets, net	180	(42)
Unrealized loss on financial instruments	221	312
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions	7,155	0
Cash advance from Holdings to contributed subsidiaries, net	(2)	54
Other, net
Changes in operating assets and liabilities:	16,951	(5,526)
Increase (Decrease) in Prepaid Expense and Other Assets	780	2,128
Increase (Decrease) in Other Noncurrent Assets	76	(20)
Increase (Decrease) in Accounts Payable and Accrued Liabilities	(31,404)	12,107
Asset Impairment Charges	193	0
Increase (Decrease) in Other Operating Liabilities	904	(855)
Net Cash Provided by (Used in) Operating Activities	4,503	23,701
Net cash provided by operating activities
Cash flows from investing activities:	(64,959)	(55,891)
Capital expenditures	100	(970)
Proceeds from Sale of Productive Assets	4,693	45
Payments to Acquire Interest in Joint Venture	(2,474)	0
Payments to Acquire Businesses and Interest in Affiliates	(15,000)	0
Expenditures for assets subject to property damage claims, net of insurance proceeds and deductibles	0	(38,636)
Net cash used in investing activities
Proceeds from Issuance of Long-term Debt	0	144,671
Proceeds from Issuance of Other Long-term Debt	102,000	134,000
Repayments of Long-term Lines of Credit	(15,000)	(174,450)
Repayments of Other Long-term Debt	(2,250)	0
Borrowings under our credit facility	(276)	(307)
Repayments under our credit facility	(602)	(166)
Contributions from general partner	1,281	3,115
Payments of Capital Distribution	(23,306)	(27,516)
Affiliate Costs	17,858	0
Payments Related to Tax Withholding for Share-based Compensation	0	(37)
Net increase in cash and cash equivalents	$ 6,568	$ 7,559

CONDENSED CONSOLIDATED STATEME7

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL - USD ($)	Total	Class B Convertible Units [Member]	Southcross Holdings Common [Member]	Southcross Holdings Common [Member]Class B Convertible Units [Member]	Common	CommonClass B Convertible Units [Member]	Class B Convertible Units [Member]	Class B Convertible Units [Member]Class B Convertible Units [Member]	Subordinated	SubordinatedClass B Convertible Units [Member]	SubordinatedSeries A Preferred Stock [Member]	SubordinatedSubordinated Units [Member]	General Partner [Member]	General Partner [Member]Class B Convertible Units [Member]	Common Units [Member]Common	Series A Convertible Preferred Units [Member]	Series A Convertible Preferred Units [Member]General Partner [Member]	valley wells [Member]	valley wells [Member]Southcross Holdings Common [Member]	valley wells [Member]Common	valley wells [Member]Class B Convertible Units [Member]	valley wells [Member]Subordinated	valley wells [Member]General Partner [Member]
Increase (Decrease) in Shareholders' Equity
Total partners' capital	$ 275,024,000		$ (210,000)		$ 169,141,000				$ 99,726,000
Net loss	(4,249,000)
Payments of Stock Issuance Costs													$ 84,000
Net loss allocated to limited partner, basic and diluted	(4,249,000)		0		(8,398,000)				(2,068,000)			$ (1,584,000)	(85,000)		$ (2,580,000)
Series A convertible preferred unit in-kind distribution and fair value adjustment	(5,029,000)
Contributions from general partner	3,115,000
Affiliate Costs	0
Payments to Acquire Businesses and Interest in Affiliates	0
Partners' Capital Account, Public Sale of Units					144,700,000
Total partners' capital	386,171,000		0		289,465,000				87,887,000				8,819,000
Total partners' capital	697,104,000		77,320,000		259,735,000		$ 298,833,000		48,831,000				12,385,000
Net loss	(29,356,000)		(4,258,000)				(7,100,000)						(561,000)
Payments of Stock Issuance Costs													502,000
Net loss allocated to limited partner, basic and diluted	(29,356,000)				(11,830,000)		(7,100,000)		(5,744,000)			$ (5,694,000)			$ (11,802,000)
Business Combination, Consideration Transferred	(15,000,000)		(77,640,000)		(62,640,000)		0		0				0
Series A convertible preferred unit in-kind distribution and fair value adjustment		$ 0		$ 0		$ (4,414,000)		$ 6,706,000		$ (2,158,000)				$ (134,000)		$ 0
Partners' Capital Account, Unit-based Compensation	2,333,000		0		2,333,000		0		0				0
Partners' Capital Account, Distributions	(23,306,000)	$ (0.44)	0		(19,040,000)		0		(3,432,000)				(834,000)
Contributions from general partner	1,281,000		0		0		0				$ 0		1,281,000				$ (800,000)
Class B Convertible unit in-kind distribution	0		0		(92,000)		0		(45,000)				(137,000)
Accrued Distribution on Long Term Incentive Plan	(444,000)		0		(444,000)		0		0				0
Affiliate Costs	17,858,000																	$ 518,000	$ 0	$ 518,000	$ 0	$ 0	$ 0
Payments to Acquire Businesses and Interest in Affiliates	15,000,000		15,000,000		0		0		0				0
Business Acquisition, Transaction Costs																		$ 17,858,000	$ 17,858,000	$ 0	$ 0	$ 0	$ 0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net	0		(28,980,000)		14,442,000		7,728,000		6,231,000				579,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities			700,000		0		0		0				0
Total partners' capital	$ 666,688,000		$ 0		$ 303,876,000		$ 306,167,000		$ 43,733,000				$ 12,912,000

ORGANIZATION AND DESCRIPTION OF

ORGANIZATION AND DESCRIPTION OF BUSINESS	6 Months Ended
	Jun. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
ORGANIZATION AND DESCRIPTION OF BUSINESS	ORGANIZATION AND DESCRIPTION OF BUSINESS Organization 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.” Until August 4, 2014, Southcross Energy LLC, a Delaware limited liability company, held all of the equity interests in Southcross Energy Partners GP, LLC, a Delaware limited liability company and our general partner (“General Partner”), all of our subordinated units and a portion of our common units. Southcross Energy LLC is controlled through investment funds and entities associated with Charlesbank Capital Partners, LLC (“Charlesbank”). Holdings Transaction On August 4, 2014, Southcross Energy LLC and TexStar Midstream Services, LP, a Texas limited partnership (“TexStar”), combined pursuant to a contribution agreement in which Southcross Holdings LP, a Delaware limited partnership (“Holdings”), was formed (the “Holdings Transaction”). As a result of the Holdings Transaction, Holdings indirectly owns 100% of our General Partner (and therefore controls us), all of our subordinated units and a portion of our common units. Our General Partner owns an approximate 2.0% interest in us and all of our incentive distribution rights. Charlesbank, EIG Global Energy Partners, LLC (“EIG”) and Tailwater Capital LLC (“Tailwater”) (collectively, the “Sponsors”) each indirectly own approximately one-third of Holdings. Affiliates of Energy Capital Partners Mezzanine Opportunities Fund and GE Energy Financial Services also own certain additional equity interests in Holdings. TexStar Rich Gas System Transaction Contemporaneously with the closing of the Holdings Transaction, TexStar contributed to us certain gathering and processing assets (the “TexStar Rich Gas System”), which were owned by TexStar (the “TexStar Rich Gas System Transaction”). For additional details regarding the Holdings Transaction and the TexStar Rich Gas System Transaction, see Notes 2, 6, 9, 10, and 13. Holdings Drop-Down Acquisition On May 7, 2015, we acquired gathering, treating, compression and transportation assets (the “2015 Holdings Acquisition”) from Holdings and its subsidiaries consisting of the Valley Wells sour gas gathering and treating system, compression assets that are part of the Valley Wells and Lancaster gathering and treating systems and two NGL pipelines. For additional details regarding the 2015 Holdings Acquisition, see Notes 2 and 9. Liquidity Consideration Beginning in the second half of 2014 and continuing through the issuance of these financial statements, commodity prices have experienced increased volatility. In particular, natural gas, crude oil and NGL prices have decreased significantly. If a material reduction in drilling occurs in the geographic areas in which we operate, including the Eagle Ford Shale region, or significant, prolonged pricing deterioration occurs for commodities we sell, our future cash flow may be materially adversely affected. The majority of our revenue is derived from fixed-fee 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. A percentage of our contract portfolio, however, contains minimum volume commitment arrangements. The majority of our volumes are dependent upon the level of producer drilling activity. After considering these uncertainties, our forecast indicates a shortfall in the amount of consolidated EBITDA (as defined in our Credit Facility (as defined in Note 6), as amended in May 2015) necessary to remain in compliance with the consolidated total leverage ratio of our Financial Covenants (as defined in Note 6) in our Credit Facility. As discussed in further detail in Note 6, we have the right to cure such a Financial Covenant Default (as defined in Note 6) by our Sponsors or Holdings purchasing equity interests in or making capital contributions (an equity cure) resulting in, among other things, proceeds that, if added to consolidated EBITDA, would result in us satisfying the Financial Covenants. Once such an equity cure is made, it is included in our consolidated EBITDA calculation in any rolling twelve month period that includes the quarter that was cured. Should there be an event of default under the Credit Facility, and such default is not cured, we would also experience a cross default under our Term Loan Agreement (defined in Note 6) and all of our debt would become due and payable to our lenders. As of June 30, 2015, we determined that we will not be in compliance with the consolidated total leverage ratio for our Financial Covenants absent an equity cure of approximately $4.7 million within approximately 15 days following the issuance of these financial statements. We believe that we will have the ability to fund this equity cure and any potential additional equity cures needed to maintain compliance with our Financial Covenants through the end of 2015 through a combination of a contractual $13.0 million non-cash equity cure credit amount from our Credit Agreement Amendment (as defined in Note 6) and the $25 million Sponsor equity commitment described below. In response to our need for additional liquidity and need to maintain compliance with our Financial Covenants as of June 30, 2015, our Sponsors have committed to provide the necessary funding to support us for at least a reasonable period of time in an amount up to $25 million to ensure we have sufficient liquidity to comply with applicable Financial Covenants, including an equity cure as of June 30, 2015, and to fund normal operating and growth capital requirements. Therefore, these financial statements have been presented as if we will continue as a going concern. See Note 6. Description of Business We are a master limited partnership 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 four gas processing plants, two fractionation facilities and our pipelines. We are headquartered in Dallas, Texas. Segments Our chief operating decision maker is our General Partner’s 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 AND SUMMA

BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	6 Months Ended
	Jun. 30, 2015
Accounting Policies [Abstract]
BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	Basis of Presentation We prepared this report under the rules and regulations of the Securities and Exchange Commission and in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim financial statements. Accordingly, these condensed consolidated financial statements do not include all of the disclosures required by GAAP and should be read in conjunction with our 2014 Annual Report on Form 10-K. The condensed consolidated financial statements as of June 30, 2015 and December 31, 2014 , and for the three and six months ended June 30, 2015 and 2014 , are unaudited and have been prepared on the same basis as the audited financial statements included in our 2014 Annual Report on Form 10-K. Adjustments (consisting of normal recurring adjustments) necessary for a fair presentation of the results of operations and financial position have been included herein. All intercompany accounts and transactions have been eliminated in the preparation of the accompanying condensed consolidated financial statements. The condensed consolidated financial statements reflect the assets acquired and liabilities assumed and the related operating results associated with (i) the Onyx pipelines acquisition beginning on March 6, 2014, (ii) the TexStar Rich Gas System Transaction and the 2015 Holdings Acquisition beginning on August 4, 2014, (iii) and the Texoz acquisition beginning on November 21, 2014. See Note 2. As a result of the Holdings Transaction, Holdings acquired a controlling equity interest in the Partnership, which was accounted for under the acquisition method of accounting in the consolidated financial statements of Holdings, whereby Holdings recorded the Partnership’s assets acquired and liabilities assumed at fair value. Additionally, because the TexStar Rich Gas System was owned by TexStar, the Partnership recorded the TexStar Rich Gas System at TexStar’s historical cost. Thus, the difference between consideration paid and the TexStar Rich Gas System’s historical cost (net book value) at August 4, 2014, the date on which the Holdings Transaction and the TexStar Rich Gas System Transaction closed, was recorded as a reduction to partners’ capital. Management concluded that the Partnership was the predecessor for accounting purposes for periods prior to August 4, 2014. We recognized the 2015 Holdings Acquisition 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 2. The accompanying unaudited condensed consolidated financial statements were prepared in conformity with GAAP, which 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 condensed consolidated financial statements and the reported amounts of revenues and expenses during the period. Actual results may differ from those estimates. Information for interim periods may not be indicative of our operating results for the entire year. The disclosures included in this report provide an update to our 2014 Annual Report on Form 10-K. 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. Significant Accounting Policies During the second quarter of 2015, there were no material changes to our significant accounting policies described in Note 1 of our 2014 Annual Report on Form 10-K. Recent Accounting Pronouncements Accounting standard-setting organizations frequently issue new or revised accounting rules. We review and evaluate new pronouncements to determine their impact, if any, on our consolidated financial statements. 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 July 2015, the Financial Accounting Standards Board (“FASB”) voted to defer the new revenue recognition standard. The standard is currently set to be effective in the first quarter of 2018. In February 2015, the FASB issued an Accounting Standards Update (“ASU”) that amended current consolidation guidance with regard to variable interest entities and voting interest entities. This standard will become effective beginning in 2016. In April 2015, the FASB issued an ASU simplifying the presentation of debt issuance costs. The amendments require that debt issuance costs related to a recognized debt liability be presented on the balance sheet as a reduction to the carrying amount of that debt liability, consistent with the presentation for debt discounts. The recognition and measurement guidance for debt issuance costs is not affected by the amendments in this ASU. This standard will become effective beginning in 2016. In April 2015, the FASB issued an ASU that specifies how to calculate historical earnings per unit for a master limited partnership with retrospectively adjusted financial statements subsequent to a drop-down acquisition. The amendments specify that for purposes of calculating historical earnings per unit under the two-class method, the earnings or losses of a transferred business before the date of a drop-down acquisition are to be allocated entirely to the general partner. In that circumstance, the previously reported earnings per unit of the limited partners would not change as a result of the drop-down acquisition. Qualitative disclosures about how the rights to the earnings or losses differ before and after the drop-down acquisition occurs for purposes of computing earnings per unit under the two-class method are also required. This standard will become effective beginning in 2016. We have elected to early adopt this ASU in this report. See Note 3.

ACQUISITION

ACQUISITION	6 Months Ended
	Jun. 30, 2015
Business Combinations [Abstract]
Acquisition	ACQUISITIONS TexStar Rich Gas System Transaction. On August 4, 2014 , contemporaneously with the closing of the Holdings Transaction, TexStar contributed to us the TexStar Rich Gas System through a contribution of TexStar’s equity interest in the entities that own the TexStar Rich Gas System (the “Contribution”). In exchange for the Contribution, we paid $80 million in cash, assumed $100 million of debt (which was immediately repaid through our Term Loan Agreement (as defined in Note 6)) and issued 14,633,000 Class B Convertible Units (the “Class B Convertible Units”). The TexStar Rich Gas System consists of a cryogenic processing plant, located in Bee County, Texas, and joint venture ownership in natural gas gathering and residue pipelines across the core producing areas extending from Dimmit to Karnes Counties, Texas in the liquids-rich window of the Eagle Ford Shale region. These pipelines are operated under split-capacity arrangements within joint venture arrangements with Targa Pipeline Partners LP (“Targa”) (see Note 13). The amount of the consideration paid over TexStar’s net book value of the assets received and liabilities assumed of the TexStar Rich Gas System was recorded as a reduction to partners’ capital as summarized as follows (in thousands): Consideration paid (1) $ 404,414 Current assets $ 1,295 Property, plant and equipment, net 255,220 Investments in joint ventures (2) 152,050 Total assets contributed 408,565 Total liabilities assumed (3) (102,776 ) Net identifiable assets contributed $ 305,789 Consideration paid in excess of net assets contributed $ 98,625 Allocation of reduction to partners' capital: Common limited partner interest $ 45,420 Class B Convertible limited partner interest 27,925 Subordinated limited partner interest 23,308 General Partner interest 1,972 Total reduction to partners' capital $ 98,625 (1) This amount was calculated as follows: $80 million of cash plus 14,633,000 Class B Convertible Units at an issue price of $22.17 , the closing price of the Partnership’s common units on August 4, 2014 . (2) Significant assets acquired through the TexStar Rich Gas System Transaction include equity interests in three joint ventures. See Note 13. (3) This amount includes $100 million of debt assumed. Onyx Pipelines Acquisition. On March 6, 2014, our subsidiary, Southcross Nueces Pipelines LLC, acquired natural gas pipelines near Corpus Christi, Texas and contracts related to these pipelines from Onyx Midstream, LP and Onyx Pipeline Company (collectively, “Onyx”) for $38.6 million in cash, net of certain adjustments as provided in the purchase agreement. The pipelines transport natural gas to two power plants in Nueces County, Texas under fixed-fee contracts that extend through 2029 and include an option to extend the agreements by an additional term of up to ten years. The contracts were renegotiated in connection with the acquisition; therefore, we considered these contracts to be assumed at fair market value. The fair values of the property, plant and equipment were based upon assumptions related to expected future cash flows, discount rates and asset lives using currently available information. We utilized a mix of the cost, income and market approaches to determine the estimated fair values of such assets. The fair value measurements and models were classified as non-recurring Level 3 measurements. We performed our assessment of the fair value of the assets acquired and liabilities assumed, and the consideration given was considered equal to the fair value of net assets acquired. As a result, no goodwill was recorded. The assessment was finalized during the second quarter of 2014 and there were no subsequent changes to the preliminary balances recorded. The fair value of the assets acquired and liabilities assumed related to the Onyx purchase price was as follows (in thousands): Purchase Price—Cash $ 38,636 Current assets $ 730 Property, plant and equipment 39,413 Total assets acquired 40,143 Current liabilities assumed (1,407 ) Other liabilities assumed (100 ) Net identifiable assets acquired $ 38,636 Unaudited Pro Forma Financial Information for Onyx Pipelines Acquisition. The following unaudited pro forma financial information for the six months ended June 30, 2014 assumes that the acquisition of pipelines from Onyx occurred on January 1, 2013 and includes adjustments for income from operations, including depreciation and amortization, as well as the effects of financing the transaction (in thousands, except unit information): Six Months Ended June 30, 2014 Total revenue $ 409,303 Net loss (4,357 ) Net loss attributable to common unitholders (8,463 ) Net loss per common unit (basic and diluted) (0.43 ) Net loss attributable to subordinated unitholders (2,109 ) Net loss per subordinated unit (basic and diluted) (0.17 ) The unaudited pro forma information is not necessarily indicative of what our statements of operations would have been if the transaction had occurred on that date, or what the financial position or results from operations will be for any future periods. For the period from March 6, 2014 through June 30, 2014 , the Onyx pipelines business contributed $1.6 million in revenues and $0.3 million in net income to our statements of operations. Texoz Acquisition. On November 21, 2014, we completed the acquisition of a natural gas gathering system in McMullen County, Texas (the “Texoz System”) from LT Gathering, LLC for $5.4 million in cash, net of certain adjustments as provided in the purchase agreement (the “Texoz Acquisition”). The Texoz System consists of eight miles of gathering pipelines within two miles of our existing rich gas pipeline network and services customers under acreage dedication contracts. Due to the immaterial amount of this transaction, no pro-forma financial information has been presented. Holdings Drop-Down Acquisition. On May 7, 2015, we completed the 2015 Holdings Acquisition 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. The acquired assets consist 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 that were under construction at the time of the transaction (and that are now operational). Total consideration for the assets was $15.0 million in cash and 4.5 million new common units, valued as of the date of closing, issued to Holdings equating to $77.6 million . We also assumed the remaining capital expenditures for the completion of the NGL pipelines that were under construction. The Valley Wells System is located in the Eagle Ford Shale region, in La Salle County, Texas. The system has sour gas treating capacity of approximately 100 MMcf/d and is supported by a 35 MMcf/d minimum volume commitment. The system is connected to our rich gas system for transport and processing. The assets acquired in the 2015 Holdings Acquisition include over 50,000 horsepower of compression capability that serve both the Valley Wells and Lancaster gathering systems located primarily in Dimmit, Frio and LaSalle counties. The NGL pipelines, which were completed in June 2015, include a Y-grade pipeline that connects our Woodsboro processing facility to Holdings’ Robstown fractionator (“Robstown”) and a propane pipeline from our Bonnie View fractionator to Robstown. Because of the common control aspects in the 2015 Holdings Acquisition, 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 Valley Wells’ and Compression Assets’ financial results for all periods ending after August 4, 2014, the date of the Holdings Transaction, and before May 7, 2015. The acquired NGL pipelines were accounted for as an asset acquisition and have been included in the historical financial statements beginning on May 7, 2015. As a carve-out transaction, the 2015 Holdings Acquisition has no cash accounts. As such, accounts receivable and accounts payable, along with certain other assets and liabilities that would be settled in cash, were the rights and obligations of Holdings as of June 30, 2015. Given their nature and the fact that carve-out financial statements are meant to represent an entity’s operations as if it had existed as of the time common control occurred, we have presented these amounts as third-party receivables and payables. The amount of the 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 106,620 Net assets contributed in excess of consideration paid $ 28,980 Allocation of increase to partners' capital: Common limited partner interest $ 14,442 Class B Convertible limited partner interest 7,728 Subordinated limited partner interest 6,231 General Partner interest 579 Total increase to partners' capital $ 28,980 (1) This amount was calculated as follows: $15.0 million of cash plus 4,500,000 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 three and six months ended June 30, 2015 , are as follows (in thousands): Three Months Ended June 30, 2015 Six Months Ended June 30, 2015 Partnership revenues $ 165,560 $ 346,109 Valley Wells System and Compression Assets revenue (1) 1,660 7,049 Combined revenues $ 167,220 $ 353,158 Partnership net loss $ (14,348 ) $ (25,098 ) Valley Wells System and Compression Assets net loss (1) (1,103 ) (4,258 ) Combined net loss $ (15,451 ) $ (29,356 ) (1) Results are fully reflected in the Partnership’s results of operations for the three and six months ended June 30, 2015 .

NET (LOSS) INCOME PER LIMITED P

NET (LOSS) INCOME PER LIMITED PARTNER UNIT AND DISTRIBUTIONS	6 Months Ended
	Jun. 30, 2015
Earnings Per Share [Abstract]
NET LOSS PER LIMITED PARTNER UNIT AND DISTRIBUTIONS	NET INCOME/LOSS PER LIMITED PARTNER UNIT AND DISTRIBUTIONS Net Income/Loss Per Limited Partner Unit The following is a reconciliation of the net loss attributable to our limited partners and our limited partner units and the basic and diluted earnings per unit calculations for the three and six months ended June 30, 2015 and 2014 (in thousands, except unit and per unit data): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Net loss $ (15,451 ) $ (2,961 ) $ (29,356 ) $ (4,249 ) Series A Preferred Unit fair value adjustment (1) — (5,062 ) — (5,029 ) Series A Preferred Unit in-kind distribution — (738 ) — (1,272 ) General partner Unit in-kind distribution (61 ) — (137 ) — Net loss attributable to Holdings (1,103 ) — (4,258 ) — Net loss attributable to partners $ (14,409 ) $ (8,761 ) $ (25,235 ) $ (10,550 ) General partner's interest (2) (306 ) (59 ) (561 ) (84 ) Class B Convertible limited partner interest (2) (3,981 ) — (7,100 ) — Limited partners' interest (2) Common (6,928 ) (7,382 ) (11,830 ) (8,398 ) Subordinated (3,194 ) (1,320 ) (5,744 ) (2,068 ) (1) The valuation adjustment to maximum redemption value of the Series A Preferred Unit in-kind distribution increased the net loss attributable to partners for the three and six months ended June 30, 2014 . (2) General Partner's and limited partners’ interests are calculated based on the allocation of net losses for the period, net of the allocation of Series A Preferred Unit in-kind distributions, Series A Preferred Unit fair value adjustments and General Partner Unit in-kind distributions. The Class B Convertible Unit interest is calculated based on the allocation of only net losses for the period. Three Months Ended June 30, Six Months Ended June 30, Common Units 2015 2014 2015 2014 Interest in net loss $ (6,928 ) $ (7,382 ) $ (11,830 ) $ (8,398 ) Effect of dilutive units - numerator (1) — — — — Dilutive interest in net loss $ (6,928 ) $ (7,382 ) $ (11,830 ) $ (8,398 ) Weighted-average units - basic 26,476,520 21,472,420 25,143,455 19,887,523 Effect of dilutive units - denominator (1) — — — Weighted-average units - dilutive 26,476,520 21,472,420 25,143,455 19,887,523 Basic and diluted net loss per common unit $ (0.26 ) $ (0.34 ) $ (0.47 ) $ (0.42 ) Three Months Ended June 30, Six Months Ended June 30, Subordinated Units 2015 2014 2015 2014 Interest in net loss $ (3,194 ) $ (1,320 ) $ (5,744 ) $ (2,068 ) Effect of dilutive units - numerator (1) — — — — Dilutive interest in net loss $ (3,194 ) $ (1,320 ) $ (5,744 ) $ (2,068 ) Weighted-average units - basic 12,213,713 12,213,713 12,213,713 12,213,713 Effect of dilutive units - denominator (1) — — — — Weighted-average units - dilutive 12,213,713 12,213,713 12,213,713 12,213,713 Basic and diluted net loss per subordinated unit $ (0.26 ) $ (0.11 ) $ (0.47 ) $ (0.17 ) (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 53,747 and 28,887 for the three and six months ended June 30, 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. All of our Series A Preferred Units were converted into common units on August 4, 2014 (see Note 8). Prior to conversion, our Series A Preferred Units were considered participating securities for purposes of the basic earnings per unit calculation during periods in which they received cash distributions. We were required to pay in-kind distributions to the Series A Preferred Units for the first four full quarters beginning the second quarter of 2013, and continued to pay these distributions until the Series A Preferred Units were converted into common units. Because the Series A Preferred Units received in-kind distributions, they have been excluded from the basic earnings per unit calculation for the three and six months ended June 30, 2014 . Distributions Our agreement of limited partnership, which was amended and restated on August 4, 2014 in order to establish the Class B Convertible Units (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. Subject to the waiver and credit agreement restriction, described below, we intend to make a minimum quarterly distribution to the holders of our common units and subordinated units of $0.40 per unit, or $1.60 on an annualized basis, to the extent we have sufficient cash from our operations after the establishment of cash reserves and the payment of costs and expenses, including reimbursements of expenses to our General Partner. However, 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 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 Credit Agreement Amendment (as defined in Note 6) imposed additional restrictions on our ability to declare and pay quarterly cash distributions with respect to our subordinated units. See Note 6. With respect to the fourth quarter of 2014, Holdings also waived the requirement that any distribution owed to it for that quarter be paid within 45 days of the end of the quarter, provided that the distribution was paid before or in conjunction with the filing of our 2014 Annual Report on Form 10-K. We paid a distribution of $0.28 per unit on our 12,213,713 subordinated units in conjunction with the filing of our 2014 Annual Report on Form 10-K. 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. Paid In-Kind Distributions Series A Preferred Units. During the second quarter of 2013, we raised $40.0 million of equity through issuances of 1,715,000 Series A Preferred Units and an additional General Partner contribution to satisfy the requirements of our Previous Credit Facility (as defined in Note 6) (see Notes 6 and 8). Under the terms of our Partnership Agreement, we were required to pay the holders of our Series A Preferred Units quarterly distributions of in-kind Series A Preferred Units for the first four full quarters following the issuance of the units and continuing thereafter until the board of directors of our General Partner determined to begin paying quarterly distributions in cash. In-kind distributions were in the form of Series A Preferred Units at a rate of $0.40 per outstanding Series A Preferred Unit per quarter (or 7% per year of the per unit purchase price). Cash distributions were required to equal the greater of $0.40 per unit per quarter or the quarterly distribution paid with respect to each common unit. In accordance with the Partnership Agreement, our General Partner received a corresponding distribution of in-kind general partner units to maintain its 2.0% interest in us. In connection with the Holdings Transaction (see Notes 1 and 2), all holders of the Series A Preferred Units elected to convert their Series A Preferred Units into 2,015,638 common units based on a 110% exchange ratio. The following table represents the paid in-kind (“PIK”) distribution declared in 2014 through August 4, 2014 , the date on which all outstanding Series A Preferred Units were converted to common units (in thousands, except per unit and in-kind distribution units): Payment Date Attributable to the Quarter Ended (1) Per Unit Distribution In-Kind Series A In-Kind Series A Distributions (2) In-Kind Unit to General Partner In-Kind General Partner Distribution Value (2) 2014 May 15, 2014 March 31, 2014 $ 0.40 31,513 $ 534 643 $ 11 (1) As a result of the conversion, the Series A Preferred Unit holders (and the corresponding General Partner units) ceased receiving PIK distributions effective with the quarter ended June 30, 2014, but received a cash distribution on the converted common units. (2) 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. Class B Convertible Units. In connection with the Contribution and the TexStar Rich Gas System Transaction, on August 4, 2014 , we established our Class B Convertible Units. As of June 30, 2015 , the Class B Convertible Units consist of 15,414,754 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 14,633,000 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 9. The following table presents the PIK distribution earned on the Class B Convertible Units for periods after issuance on August 4, 2014 through June 30, 2015 (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) 2015 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 2014 February 13, 2015 December 31, 2014 0.3257 260,558 4,143 5,318 85 November 14, 2014 September 30, 2014 0.3257 256,078 5,467 5,226 112 (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. Cash Distributions The following table represents our distributions declared for the quarterly periods beginning in 2014 through the six months ended June 30, 2015 (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 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 2014 February 13, 2015 December 31, 2014 0.40 (1) 9,520 3,432 (2) 416 13,368 November 14, 2014 September 30, 2014 0.40 (1) 9,520 — 413 9,933 August 14, 2014 June 30, 2014 0.40 9,399 4,886 290 14,575 May 15, 2014 March 31, 2014 0.40 8,586 4,886 290 13,762 (1) The common unit distribution in the table above includes the distribution payment to the Series A Preferred unitholders for their Series A Preferred Units converted into common units or to the units that vested as part of our LTIP (as defined in Note 11) as a result of the Holdings Transaction (see Notes 1, 8 and 11). (2) Holdings waived the requirement that any distribution owed to it for the fourth quarter be paid within 45 days of the end of the quarter. We paid a distribution of $0.28 per unit on our 12,213,713 subordinated units in conjunction with the filing of our 2014 Annual Report on Form 10-K.

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	6 Months Ended
	Jun. 30, 2015
Investments, All Other Investments [Abstract]
FINANCIAL INSTRUMENTS	FINANCIAL 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, accounts receivable and accounts payable. • 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 the debt funded through our credit facilities 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. Derivative Financial Instruments Interest Rate Derivative Transactions We manage a portion of our interest rate risk through interest rate swaps and interest rate caps. In March 2012, we terminated an interest rate cap contract and entered into an interest rate swap contract with Wells Fargo, N.A. The interest rate swap had a notional value of $150.0 million , and a maturity date of June 30, 2014. We received a floating rate based upon one-month London Interbank Offered Rate (“LIBOR”) and paid a fixed rate under the interest rate swap of 0.54% . The interest rate swap was designated as a cash flow hedge for accounting purposes at inception of the contract and, thus, to the extent the cash flow hedge was effective, unrealized gains and losses were recorded to accumulated other comprehensive income/loss and recognized in interest expense as the underlying hedged transactions (interest payments) were recorded. Any hedge ineffectiveness was recognized in interest expense immediately. We did not have any hedge ineffectiveness during the three and six months ended June 30, 2014 . In February 2014, we discontinued cash flow hedge accounting on a prospective basis as a result of the $148.5 million repayment of borrowings under our Previous Credit Facility (as defined in Note 6). The fair value of the interest rate swap recorded in accumulated other comprehensive loss at the cash flow hedge de-designation date was $0.1 million . This balance was reclassified into interest expense as interest on the hedged debt was recorded. No ineffectiveness was recorded as a result of the cash flow hedge de-designation. Changes in the fair value of the interest rate swap for the remainder of the contract term were recognized in interest expense. The effect of the interest rate swap designated as a cash flow hedge in our statements of changes in partners’ capital and comprehensive loss was as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2014 2014 Change in value recognized in other comprehensive loss - effective portion $ — $ (11 ) Loss reclassified from accumulated other comprehensive loss to interest expense 106 221 There were no amounts of gains or losses reclassified into earnings as a result of the discontinuance of cash flow hedge accounting due to the lack of probability of the forecasted transaction occurring. 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 June 30, 2015 $ 50,000 1.198 % September 30, 2014 June 30, 2016 $ (88 ) 50,000 1.196 % September 30, 2014 June 30, 2016 (88 ) 100,000 1.195 % June 30, 2015 January 1, 2017 (138 ) $ (314 ) We enter into interest rate cap contracts to effectively limit our 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 June 30, 2015 $ 20,000 1.500 % December 31, 2014 December 31, 2016 $ 12 80,000 3.000 % June 30, 2015 June 30, 2017 32 $ 44 These interest rate derivatives are not designated as cash flow hedges 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. The fair values of our interest rate derivatives were as follows (in thousands): Significant Other Observable Inputs (Level 2) Fair Value Measurement as of June 30, 2015 December 31, 2014 Current interest rate derivative assets $ 24 $ 27 Non-current interest rate derivative assets 20 27 Current interest rate derivative (liabilities) (268 ) (175 ) Non-current interest rate derivative (liabilities) (46 ) (39 ) Total interest rate derivatives $ (270 ) $ (160 ) The realized and unrealized amounts recognized in interest expense associated with derivatives that are not designated as hedging instruments were as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Unrealized loss on interest rate derivatives $ 54 $ 168 $ 109 $ 180 Realized loss on interest rate derivatives 154 27 258 53 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 had no outstanding month-ahead swap contracts as of June 30, 2015 . The total volume of outstanding month-ahead swap contracts as of December 31, 2014 was 12,000 MMBtu per day. 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. We did not have any cash collateral received or paid on our commodity swaps as of June 30, 2015 or December 31, 2014 . The effect of offsetting on our balance sheets was as follows (in thousands): June 30, 2015 December 31, 2014 Other Current Assets Other Current Liabilities Other Current Assets Other Current Liabilities Gross amounts of recognized assets $ — $ — $ 112 $ — Gross amounts offset on the balance sheets — — — — Net amount $ — $ — $ 112 $ — The realized and unrealized gain/loss on these derivatives, recognized in revenues in our statements of operations, was as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Realized gain (loss) on commodity swap derivatives $ 125 $ 81 $ 136 $ (1,088 ) Unrealized loss on commodity swap derivatives — (175 ) (112 ) (131 )

LONG-LIVED ASSETS

LONG-LIVED ASSETS	6 Months Ended
	Jun. 30, 2015
Property, Plant and Equipment [Abstract]
LONG-LIVED ASSETS	LONG-LIVED ASSETS Property, Plant and Equipment Property, plant and equipment consisted of the following (in thousands): Estimated Useful Life (yrs) June 30, 2015 December 31, 2014 Pipelines 15-30 $ 511,766 $ 488,592 Gas processing, treating and other plants 15 545,036 515,080 Compressors 7-15 69,082 62,741 Rights of way and easements 15 37,018 37,238 Furniture, fixtures and equipment 5 3,735 3,671 Capital lease vehicles 3-5 2,406 2,076 Total property, plant and equipment 1,169,043 1,109,398 Accumulated depreciation and amortization (176,809 ) (142,234 ) Total 992,234 967,164 Construction in progress 70,891 63,858 Land and other 24,372 27,548 Property, plant and equipment, net $ 1,087,497 $ 1,058,570 Depreciation is provided using the straight-line method based on the estimated useful life of each asset. In January 2015, we shut down our Gregory facility for four weeks due to a fire at the facility. In connection with the fire, as of June 30, 2015 , we reached our insurance deductible as part of efforts to return the facility to service and recorded a receivable in our condensed consolidated balance sheets for amounts incurred above the deductible. Intangible Assets Intangible assets of $1.5 million as of June 30, 2015 and December 31, 2014 , 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	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT Our outstanding debt and related information at June 30, 2015 and December 31, 2014 are as follows (in thousands): June 30, 2015 December 31, 2014 Revolving credit facility due 2019 $ 117,000 $ 30,000 Term loans (including OID of $2.0 million) due 2021 443,549 445,629 Total long-term debt (including current portion) 560,549 475,629 Current portion of long-term debt $ (4,500 ) $ (4,500 ) Total long-term debt $ 556,049 $ 471,129 Outstanding letters of credit $ 22,480 $ 30,130 Remaining unused borrowings $ 60,520 $ 139,870 Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Weighted average interest rate 5.15 % 2.70 % 5.13 % 3.60 % Average outstanding borrowings $ 276,441 $ 189,993 $ 265,537 $ 191,567 Maximum borrowings $ 563,625 $ 226,850 $ 563,625 $ 267,300 Previous Credit Facility In November 2012, we entered into a five -year $350.0 million revolving credit facility (as amended, the “Previous Credit Facility”). Borrowings under the Previous Credit Facility were set to mature in November 2017. We utilized the Previous Credit Facility for working capital requirements and capital expenditures, the purchase of assets, the payment of distributions and other general purposes. During 2013 and the first quarter of 2014, we entered into a total of four amendments to the Previous Credit Facility. In connection with these amendments, our availability was reduced from $350.0 million to the sum of $250.0 million plus any amounts placed on deposit in a collateral account of our General Partner and letters of credit outstanding. This availability was increased to $350.0 million in connection with the fourth amendment in March 2014. In connection with the closing of the TexStar Rich Gas System Transaction, we refinanced our Previous Credit Facility and entered into the Senior Credit Facilities (as defined below). Senior Credit Facilities On August 4, 2014 , in connection with the consummation of the Contribution and TexStar Rich Gas System Transaction, we entered into (a) a Third Amended and Restated Revolving Credit Agreement with Wells Fargo Bank, N.A., as Administrative Agent, UBS Securities LLC and Barclays Bank PLC, as Co-Syndication Agents, JPMorgan Chase Bank, N.A., as Documentation Agent, and a syndicate of lenders (the “Third A&R Revolving Credit Agreement”) and (b) a Term Loan Credit Agreement with Wells Fargo Bank, N.A., as Administrative Agent, UBS Securities LLC and Barclays Bank PLC, as Co-Syndication Agents, and a syndicate of lenders (the “Term Loan Agreement” and, together with the Third A&R Revolving Credit Agreement, the “Senior Credit Facilities”). The initial borrowings and extensions of credit under the Term Loan Agreement were used to finance the TexStar Rich Gas System Transaction (including the immediate repayment of the $100 million of debt assumed in the transaction), the repayment of certain of our existing debt and the payment of fees and expenses in connection with the new debt arrangements and ongoing working capital and other general partnership purposes. No amounts were initially drawn on the Third A&R Revolving Credit Agreement. 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 (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 increased to $75 million ; (b) we have the right to increase the total commitments under the Credit Facility by obtaining additional commitments from other lenders, as long as our senior secured leverage ratio is less than or equal to 4.50 to 1.00 before and after giving effect to such increase, subject to certain other conditions; (c) the definition of “Change of Control” is amended to permit the combination transaction with TexStar and to reflect the Sponsors’ control of the General Partner; (d) our maximum consolidated total leverage ratio (i) was set at 5.75 to 1.00 as of the last day of the fiscal quarter ending each of September 30, 2014 and December 31, 2014, (ii) is set at 5.50 to 1.00 as of the last day of the fiscal quarter ending March 31, 2015, (iii) 5.25 to 1.00 as of the last day of the fiscal quarter ending June 30, 2015 and (iv) 5.00 to 1.00 as of the last day of each fiscal quarter thereafter; (e) we had the right, exercisable on or before the date that our annual audited financial statements were due for the 2014 fiscal year, to comply with the consolidated total leverage ratio, consolidated senior secured leverage ratio and the consolidated interest coverage ratio covenants (the “Financial Covenants”) by applying certain specified quarterly base periods and annualization methods pertaining to the TexStar Rich Gas System; (f) if we fail to comply with the Financial Covenants (a “Financial Covenant Default”), we have the right (which cannot be exercised more than two times in any twelve month period or more than four times during the term of the facility) 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; (g) certain definitions are amended to take into account the TexStar Rich Gas System; and (h) the negative covenants are amended to permit the entry into, and indebtedness under, the Term Loan Agreement. Amendment to Third A&R Revolving Credit Agreement During the fourth quarter of 2014 and into the first quarter of 2015 , as a result of the decline in commodity prices and associated decline in upstream drilling activity, we experienced a decline in the growth in volume of natural gas we gather and process for our customers. Our results in the first quarter of 2015 were also negatively impacted by the fire at our Gregory facility (see Note 5). These collective events impacted our operating results adversely and resulted in the need to amend our Third A&R Revolving Credit Agreement. On May 7, 2015, we entered into a First Amendment to our Third A&R Revolving Credit Agreement among the Partnership, as the borrower, Wells Fargo, N.A., as the administrative agent, the lenders and other parties thereto (the “Credit Agreement Amendment”). The Credit Agreement Amendment amended the Third A&R Revolving Credit Agreement. The Credit Agreement Amendment, among other things: (a) (i) revised the maximum consolidated total leverage ratio set at 5.75 to 1.0 as of the last day of the fiscal quarter ending each of March 31, 2015, June 30, 2015 and September 30, 2015, (ii) 5.5 to 1.0 as of the last day of the fiscal quarter ending each of December 31, 2015, March 31, 2016 and June 30, 2016, (iii) 5.25 to 1.0 as of the last day of the fiscal quarter ending September 30, 2016, and (iv) 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; (b) 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% ; (c) permits the Partnership to comply with certain Financial Covenants by making certain pro forma adjustments with respect to minimum revenues to be received from Frio; (d) modified our ability to cure Financial Covenant defaults; (e) imposed additional restrictions on our ability to declare and pay quarterly cash distributions with respect to our subordinated units; (f) amended certain other provisions of the Third A&R Revolving Credit Agreement as more specifically set forth in the Credit Agreement Amendment; and (g) allows 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. Additionally, we are unable to borrow on our Credit Facility until we have funded the required equity cure for the second quarter of 2015; however, we retain the ability to fund the required equity cure using a contractual non-cash credit amount of up to $13 million . Term Loan Agreement The Term Loan Agreement is a seven-year $450 million senior secured term loan facility. On August 4, 2014 , the lenders funded the full amount of the facility. 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% . Under the Term Loan Agreement, among other things: (a) subject to certain requirements, including the absence of a default and pro forma compliance under the Third A&R Revolving Credit Agreement and pro forma compliance with a senior secured leverage ratio less than or equal to 4.50 to 1.00 before and after giving effect to such increase, we may from time to time request incremental term loan commitments subject to certain other conditions; (b) we may seek commitments from third party lenders in connection with any incremental term loan commitment requests, subject to certain consent rights given to the administrative agent; (c) the guarantors and the collateral are the same as provided for the benefits of the lenders in the Third A&R Revolving Credit Agreement; (d) subject to certain conditions, we may request that the lenders extend the seven -year maturity of all or a portion of the outstanding loans under the facility; (e) the facility will amortize 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; (f) there are customary mandatory prepayment provisions and, subject to certain conditions, permissive prepayment provisions; provided, that if certain repricing transactions occur, we must pay a call premium equal to 1% of the principal amount of the loans subject to the repricing transactions; and (g) there are customary representations and warranties, affirmative covenants, negative covenants and provisions governing an event of default (including acceleration of payment in connection with material indebtedness, including the Third A&R Revolving Credit Agreement).

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	6 Months Ended
	Jun. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES Legal Matters On March 5, 2013, one of our subsidiaries, Southcross Marketing Company Ltd., filed suit in a District Court of Dallas County, Texas, 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. After a bench trial held in January 2015, on February 5, 2015, the judge ruled that Formosa breached certain of its obligations under the gas processing and sales contract and that our subsidiary breached an obligation under each of the gas processing and sales contract and the related residue gas agreement. The amount of damages awarded to our subsidiary was in excess of the damages awarded to Formosa. Rather than wait for the judge to award attorneys’ fees for each party as to the claims on which it prevailed, the parties have reached an agreement as to the appropriate award of attorneys’ fees. The amount of attorneys’ fees to be paid to our subsidiary is in excess of the attorneys’ fees to be paid to Formosa. After the ruling, our subsidiary filed a motion for reconsideration regarding a claim that was dismissed before trial through summary judgment. Formosa filed its own motion for reconsideration regarding the amount of damages awarded to our subsidiary on one of its claims. A hearing on both motions for reconsideration was held on June 5, 2015. The judge has yet to issue a ruling on these motions. Even if Formosa is successful in its request to reduce the damages awarded to our subsidiary, the amount of damages awarded to our subsidiary would still be in excess of the damages awarded to Formosa. No judgment will be entered until the judge has made a ruling on these motions. Regardless of how the judge rules on these motions, the judgment is not expected to have a material impact on our results of operations, cash flows or financial condition. 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 are currently involved in several such proceedings and disputes, our management believes that no ne 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. 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 that are classified as capital leases. The termination dates of the lease agreements vary from 2015 to 2019. We recorded amortization expense related to the capital leases of $0.1 million and $0.3 million for the three and six months ended June 30, 2015 and $0.1 million and $0.3 million for the three and six months ended June 30, 2014 . Capital leases entered into during the three and six months ended June 30, 2015 were $0.2 million and $0.4 million , respectively. Capital leases entered into during the three and six months ended June 30, 2014 were $0.1 million and $0.5 million . The capital lease obligation amounts included on the balance sheets were as follows (in thousands): June 30, 2015 December 31, 2014 Other current liabilities $ 435 $ 455 Other non-current liabilities 664 578 Total $ 1,099 $ 1,033 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 2015 to 2025. Expenses associated with operating leases, which are recorded in operations and maintenance expenses and general and administrative expenses in our statements of operations, were $0.6 million and $1.7 million for the three and six months ended June 30, 2015 , respectively. A rental reimbursement included in our lease agreement associated with the office space we leased in June 2015 of $1.1 million has been recorded as a deferred liability on our condensed consolidated balance sheets as of June 30, 2015. This amount will be amortized against the lease payments over the length of the lease term. Expenses associated with operating leases were $0.4 million and $0.7 million for the three and six months ended June 30, 2014 , respectively. Purchase Commitments At June 30, 2015 , we had commitments of approximately $25.7 million primarily related to the purchase of pipelines and compressors for our various capital expansion projects. We have other planned capital projects that are discretionary in nature, with no substantial contractual capital commitments made in advance of the actual expenditures.

TRANSACTIONS WITH RELATED PARTI

TRANSACTIONS WITH RELATED PARTIES	6 Months Ended
	Jun. 30, 2015
Related Party Transactions [Abstract]
TRANSACTIONS WITH RELATED PARTIES	TRANSACTIONS WITH RELATED PARTIES Charlesbank, EIG & Tailwater (our Sponsors) Effective August 4, 2014, in connection with the Contribution and as a result of the Holdings Transaction, the board of directors of our General Partner includes one director affiliated with Charlesbank, one director affiliated with EIG, one director affiliated with Tailwater and three outside directors. On July 15, 2015, a fourth outside director was elected to serve on the board of directors of our General Partner. The eighth member of the board of directors of our General Partner, and its chairman, is David W. Biegler. Mr. Biegler will serve as chairman until the earlier of August 4, 2016 and his death or resignation. 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): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Charlesbank $ 42 $ 110 $ 80 $ 215 EIG 17 — 33 — Tailwater 17 — 33 — Total fees and expenses paid for director services to affiliated entities $ 76 $ 110 $ 146 $ 215 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 employees required to manage and operate our business. We incurred expenses related to these reimbursements as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Reimbursements included in general and administrative expenses $ 3,845 $ 3,576 $ 7,080 $ 7,051 Reimbursements included in operations and maintenance expenses 5,133 4,113 10,432 8,056 Total reimbursements to our General Partner and its affiliates $ 8,978 $ 7,689 $ 17,512 $ 15,107 Compensation expense for services incurred by us on behalf of Southcross Energy LLC was billed to Southcross Energy LLC. For the three and six months ended June 30, 2015 , compensation expense, which was not incurred on our behalf, of $0.2 million and $0.4 million respectively was billed to Southcross Energy LLC. For the three and six months ended June 30, 2014 , $0.3 million was incurred by us and billed to Southcross Energy LLC. Wells Fargo Bank, N.A. Under our Senior Credit Facilities, Wells Fargo Bank, N.A. serves as the administrative agent (and served in that same capacity under our Previous Credit Facility). See Note 6. An affiliate of Wells Fargo Bank, N.A. is a member of our investor group. We entered into amendments to our Previous Credit Facility during 2013 and 2014. In addition, in connection with the TexStar Rich Gas System Transaction, during the third quarter of 2014, we entered into the Senior Credit Facilities, which include syndicates of financial institutions and other lenders. Affiliates of Wells Fargo Bank, N.A. have from time to time engaged in commercial banking and financial advisory transactions with us in the normal course of business. For each of the three and six months ended June 30, 2015 we incurred costs, excluding interest, to Wells Fargo Bank, N.A. and its affiliates of $0.4 million and $0.7 million , respectively, compared to $0.2 million for each of the three and six months ended June 30, 2014 . Other Transactions with Affiliates Under the Distribution Agreement, we made customary representations, warranties and agreements, including an agreement to indemnify the Managers for certain liabilities under the Securities Act. The Managers and certain of their affiliates have engaged, and may in the future engage, in commercial and investment banking transactions with us in the ordinary course of their business for which they have received, and expect to receive, customary compensation and expense reimbursement. In particular, affiliates of each of the Managers are lenders under our Senior Credit Facilities, an affiliate of Wells Fargo Securities, LLC is a lender under our Senior Credit Facilities and affiliates of the other sales agents may from time to time hold positions under the Term Loan Agreement. If we use any net proceeds of this offering to repay borrowings under our Senior Credit Facilities, such affiliates of the Managers will receive proceeds of the offering. In conjunction with the TexStar Rich Gas System Transaction, we entered into 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 agreements, we transport, process and sell rich natural gas for the affiliate of Holdings in return for fees that are substantially equivalent to the fees that Holdings receives from its customers for such services, and we can sell natural gas liquids that we own to Holdings at prices that are substantially equivalent to prices that Holdings receives from third parties. The NGL Agreement also permits us to utilize Holdings’ fractionation services at market-based rates. In conjunction with the 2015 Holdings Acquisition, we entered into 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 has been capped at $1.7 million per quarter, which has been pro-rated for the second quarter of 2015. In the second quarter of 2015, we exceeded this cap by $0.5 million which was recorded as a receivable from Holdings on our condensed consolidated balance sheets. During the three and six months ended June 30, 2015 , the Partnership recorded revenues from affiliates of $21.1 million and $28.5 million , respectively, in accordance with the G&P Agreement, the NGL Agreement and the commercial agreements entered into in connection with the 2015 Holdings Acquisition. Accounts receivable due from affiliates of $19.8 million as of June 30, 2015 is comprised of primarily (a) $16.9 million due from TexStar, (b) $1.4 million due from Holdings relating to gathering and processing services in the period and (c) $1.4 million , $17.2 thousand and $0.1 million due from T2 Eagle Ford, T2 Cogen and T2 LaSalle (each as defined in Note 13), respectively, representing reimbursements for operating costs and equipment for this investment in the joint ventures. Accounts payable due to affiliates of $14.3 million as of June 30, 2015 is comprised of primarily (a) $13.0 million due to TexStar and (b) $0.4 million , $0.5 million and $42.4 thousand due to T2 Cogen, T2 Eagle Ford and T2 LaSalle, respectively, representing operational obligations, and $0.3 million due to our General Partner.

SERIES A PREFERRED UNITS

SERIES A PREFERRED UNITS	6 Months Ended
	Jun. 30, 2015
Preferred Units Description and Other Disclosures [Abstract]
SERIES A PREFERRED UNITS	PREFERRED UNITS During the second quarter of 2013, we entered into a Series A Convertible Preferred Unit Purchase Agreement (the “Purchase Agreement”) with Southcross Energy LLC, pursuant to which we issued and sold 1,715,000 Series A Preferred Units to Southcross Energy LLC for a cash purchase price of $22.86 per unit, in a privately negotiated transaction (the “Private Placement”). Southcross Energy LLC sold 1,500,000 of these Series A Preferred Units to third parties during the second quarter of 2013. All of the Series A Preferred Units, including units held by Southcross Energy LLC, were converted to common units on August 4, 2014 in connection with the Holdings Transaction. See Notes 1 and 9.

PARTNERS' CAPITAL

PARTNERS' CAPITAL	6 Months Ended
	Jun. 30, 2015
Partners' Capital Notes [Abstract]
PARTNERS' CAPITAL	PARTNERS’ CAPITAL Ownership Our units outstanding as of June 30, 2015 are as follows (in units): Owned by Parent Partners’ Capital Public 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 In-kind distributions and general partner issuances to maintain 2.0% ownership — — 525,676 — 102,783 Common unit issuance related to the 2015 Holdings Acquisition — 4,500,000 — — — Board of Director grants 10,730 — — — — Units outstanding as of June 30, 2015 21,695,273 6,616,400 15,414,754 12,213,713 1,141,635 Common Units Our common units represent limited partner interests in us. The holders of our common units are entitled to participate in partnership distributions and are entitled to exercise the rights and privileges available to limited partners under our Partnership Agreement. In February 2014, we completed a public equity offering of 9,200,000 additional common units and we received a capital contribution from our General Partner to maintain its 2.0% interest in us. The proceeds from the public offering were $144.7 million before estimated expenses of $0.4 million related to the offering. The net proceeds from the offering were used for our Onyx acquisition in March 2014, to fund the construction of our pipeline system extending into Webb County, Texas and for general partnership purposes. In connection with the TexStar Rich Gas System Transaction and the Holdings Transaction on August 4, 2014 , we issued Class B Convertible Units, accelerated the vesting of awards under our LTIP (see Note 11), and all of the holders of our Series A Preferred Units elected to convert their Series A Preferred Units into common units based on an exchange ratio of 110% . On May 7, 2015, we completed the 2015 Holdings Acquisition for total consideration of $77.6 million , consisting of 4.5 million new common units, valued as of the date of closing and issued to Holdings, and $15.0 million in cash. Class B Convertible Units In connection with the TexStar Rich Gas System Transaction, on August 4, 2014 , we established our Class B Convertible Units. The Class B Convertible Units consist of 14,633,000 of such units plus any additional Class B PIK Units. 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. Our Partnership Agreement provides that we will procure the listing of the common units issuable upon conversion of the Class B Convertible Units on the New York Stock Exchange or other applicable national securities exchange. Distribution Rights: Commencing with the third quarter of 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. 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 (a) make a quarterly distribution equal to or greater than $0.44 per common unit, (b) 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 (c) 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. Changes in Partners’ Capital due to Holdings Transaction As discussed in Note 1, on August 4, 2014, Southcross Energy LLC and TexStar combined. As a result of this transaction, Holdings, through a wholly-owned subsidiary, (a) acquired 100% of TexStar and its general partner from BBTS Borrower LP and (b) acquired 2,116,400 of our common units and 12,213,713 of our subordinated units from Southcross Energy LLC. Thus, as a result of that transaction, Holdings acquired an approximate 57.4% limited partner interest in us at that time, as well as 100% of our General Partner, which owns an approximate 2.0% interest in us and our incentive distribution rights. BBTS Borrower LP was controlled by EIG and Tailwater. In December 2014, BBTS Borrower LP distributed to each of EIG and Tailwater, in relatively equal proportions, its interest in Holdings. Southcross Energy LLC is controlled by Charlesbank. The Holdings Transaction resulted in our Sponsors each indirectly owning approximately one-third of Holdings. Affiliates of Energy Capital Partners Mezzanine Opportunities Fund and GE Energy Financial Services also own certain additional equity interests in Holdings. 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 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 6. With respect to the fourth quarter of 2014, Holdings also waived the requirement that any distribution owed to it for that quarter be paid within 45 days of the end of the quarter, provided that the distribution was paid before or in conjunction with the filing of our 2014 Annual Report on Form 10-K. We paid a distribution of $0.28 per unit on our 12,213,713 subordinated units in conjunction with the filing of our 2014 Annual Report on Form 10-K. 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 from our general partner units purchased in connection with the Private Placement (see Note 8) and the Class B Convertible Units. In connection with other equity issuances, including issuances related to the TexStar Rich Gas System Transaction and the Holdings Transaction, our General Partner has made capital contributions in exchange for an issuance of additional general partner units to maintain its 2.0% ownership interest in us. Also, the General Partner has received general partner unit PIK distributions from the general partner units purchased in connection with the Private Placement (see Note 8). Equity Distribution Agreement On November 12, 2014, we established a $75 million "at-the-market" equity offering program pursuant to an equity distribution agreement (the “Distribution Agreement”) with Wells Fargo Securities, LLC, J.P. Morgan Securities LLC and RBC Capital Markets, LLC (each, a “Manager” and, collectively, the “Managers”). Under the Distribution Agreement, we may offer and sell up to $75 million in aggregate gross sales proceeds of our common units (the “Offered Units”) from time to time through the Managers, each as our sales agent. Sales of the Offered Units, if any, made under the Distribution Agreement will be made by means of ordinary brokers’ transactions on the New York Stock Exchange at market prices prevailing at the time of sale in block transactions, or as otherwise agreed upon by us and any Manager. The Offered Units have been registered under the Securities Act of 1933, as amended (the “Securities Act”), pursuant to Registration No. 333-192105 declared effective December 10, 2013 (the "Registration Statement"), including the prospectus contained therein, as supplemented by the prospectus supplement filed with the SEC on November 12, 2014. We intend to use the net proceeds from the sale of the Offered Units for general partnership purposes, including the repayment of debt, acquisitions and funding capital expenditures. The Distribution Agreement contains customary representations, warranties and agreements by us, including our obligations to indemnify the Managers for certain liabilities under the Securities Act. The Managers and certain of their affiliates have engaged, and may in the future engage, in commercial and investment banking transactions with us in the ordinary course of their business for which they have received, and expect to receive, customary compensation and expense reimbursement. In particular, affiliates of each of the Managers are lenders under our Senior Credit Facilities, an affiliate of Wells Fargo Securities, LLC is a lender under our Term Loan Agreement, and affiliates of the other sales agents may from time to time hold positions under the Term Loan Agreement. If we use any net proceeds of this offering to repay borrowings under our Senior Credit Facilities, such affiliates of the Managers will receive proceeds of the offering.

INCENTIVE COMPENSATION

INCENTIVE COMPENSATION	6 Months Ended
	Jun. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
INCENTIVE COMPENSATION	INCENTIVE COMPENSATION Unit Based Compensation Long-Term Incentive Plan On November 7, 2012, and in connection with our initial public offering, we established the 2012 Long-Term Incentive Plan (“LTIP”), which provides incentive awards to eligible officers, employees and directors of our General Partner. Awards granted to employees under the LTIP vest over a three -year period in equal annual installments or in the event of a change in control of our General Partner 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. The following table summarizes information regarding awards of units granted under the LTIP: Units Weighted-Average Fair Unvested - December 31, 2014 470,750 $ 20.45 Granted units 390,378 $ 13.84 Forfeited units (145,688 ) $ 19.53 Units recaptured for tax withholdings (10,667 ) $ 21.69 Vested units (44,425 ) $ 19.03 Unvested - June 30, 2015 660,348 $ 17.84 For the six months ended June 30, 2015 and 2014 , we granted awards under the LTIP with a grant date fair value of $5.4 million and $5.4 million , respectively, which we have classified as equity awards. As of June 30, 2015 and 2014 , we had total unamortized compensation expense of $9.1 million and $7.5 million , respectively, related to unvested awards. Compensation expense associated with awards granted in the six months ended June 30, 2015 of 84,423 units are expected to be recognized over a one -year vesting period, while the remaining awards are expected to be recognized over the three -year vesting period from each equity award’s grant date. As of June 30, 2015 and 2014 , we had 666,261 and 1,213,642 units, respectively, 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 have a one-year vesting period rather than a three -year vesting period. These executive awards were not compensation earned for performance in 2014 . 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): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Unit-based compensation $ 1,662 $ 1,082 $ 2,475 $ 1,611 Accelerated Vesting of Common Units In conjunction with the departure of our Chief Financial Officer in the second quarter of 2015, 38,997 outstanding phantom units granted to him under the LTIP vested (and certain accumulated distribution equivalent rights were paid), pursuant to a general release agreement. The Partnership recognized $0.5 million in general and administrative expenses in the condensed consolidated statements of operations for the three and six months ended June 30, 2015 in connection with the accelerated vesting of these units. Employee Savings Plan We have employee savings plans under Sections 401(a) and 401(k) of the Internal Revenue Code of 1986, 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 each employee’s contribution up to the lesser of 6% of the employee’s eligible compensation or $17,500 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): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Matching contributions expensed for employee savings plan $ 172 $ 234 $ 340 $ 590 2014 Incentive Plan On August 4, 2014 , our General Partner and Southcross GP Management Holdings, LLC, a Delaware limited liability company of which Holdings is the sole managing member (“GP Management”), adopted the Southcross Energy Partners GP, LLC and Southcross GP Management Holdings, LLC 2014 Equity Incentive Plan (the “2014 Incentive Plan”). Under the 2014 Incentive Plan, employees, consultants and directors of our General Partner and GP Management will be eligible to receive incentive compensation awards. The 2014 Incentive Plan generally provides for the grant of awards, from time to time at the discretion of the board of directors of our General Partner (and, as applicable, the board of directors of the general partner of Holdings), of non-voting units in our General Partner to GP Management and then a corresponding grant or award of non-voting units of GP Management to the employee, consultant or director. In connection with the adoption of the 2014 Incentive Plan, our General Partner amended and restated its limited liability company agreement and entered into its Second Amended and Restated Limited Liability Company Agreement which establishes a new class of non-voting units for issuance pursuant to the 2014 Incentive Plan and designates Southcross Holdings Borrower LP, a wholly owned subsidiary of Holdings as our General Partner’s managing member. As of June 30, 2015 , no awards had been granted under this plan.

REVENUES

REVENUES	6 Months Ended
	Jun. 30, 2015
Revenues [Abstract]
REVENUES	REVENUES We had revenues consisting of the following categories (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Sales of natural gas $ 92,518 $ 123,401 $ 205,304 $ 268,759 Sales of NGLs and condensate 39,427 54,282 76,610 106,155 Transportation, gathering and processing fees 33,823 17,279 68,876 33,394 Other 1,452 101 2,368 346 Total revenues $ 167,220 $ 195,063 $ 353,158 $ 408,654

CONCENTRATION OF CREDIT RISK AN

CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE	6 Months Ended
	Jun. 30, 2015
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 three and six months ended June 30, 2015 and 2014 represent the following percentages of consolidated revenue: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Top ten customers 55.8 % 73.0 % 56.8 % 68.6 % The percentage of total consolidated revenue for each customer that exceeded 10% of total revenues for the three and six months ended June 30, 2015 and 2014 was as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Sherwin Alumina Company (a) 12.2 % (a) 11.0 % Trafigura AG 13.0 % 13.0 % 11.8 % 12.6 % (a) Information is not provided for periods for which the customer or producer was less than 10% of our consolidated revenue. For the six months ended June 30, 2015 and 2014 , we did not experience significant non-payment for services. At June 30, 2015 and December 31, 2014 , we did not record an allowance for uncollectible accounts receivable.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	6 Months Ended
	Jun. 30, 2015
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS Partnership Distributions On July 30, 2015, the board of directors of our General Partner declared a cash distribution of $0.40 per common unit and General Partner unit, which will be paid on August 14, 2015 to unitholders of record on August 10, 2015. In addition, on July 30, 2015, the board of directors of our General Partner declared a $0.3257 per unit distribution for the second quarter of 2015 on our Class B Convertible Units. The distribution on the Class B Convertible Units will be paid in the form of additional Class B Convertible Units on August 14, 2015. In order to support our acquisition of the TexStar Rich Gas System in August 2014, Holdings has elected to forgo distributions on any subordinated units that would cause our distributions to exceed our distributable cash flow for any quarterly period. This election will continue until we have distributable cash flow in excess of total distributions on our common and subordinated units. We must also comply with additional restrictions on our ability to declare and pay quarterly cash distributions on our subordinated units in the Credit Agreement Amendment.

SUPPLEMENTAL INFORMATION

SUPPLEMENTAL INFORMATION	6 Months Ended
	Jun. 30, 2015
Supplemental Cash Flow Elements [Abstract]
SUPPLEMENTAL INFORMATION	SUPPLEMENTAL INFORMATION Supplemental Cash Flow Information (in thousands) Six Months Ended June 30, 2015 2014 Supplemental Disclosures: Cash paid for interest, net of amounts capitalized $ 14,221 $ 4,200 Cash received for tax refunds 58 185 Supplemental disclosures of non-cash investing and financing activities: Accounts payable related to capital expenditures 9,615 9,656 Change in value recognized in other comprehensive loss — 11 Capital lease obligations 342 466 Accrued distribution equivalent rights on LTIP units 444 259 Class B Convertible unit in-kind distributions 6,706 — Net assets contributed in Holdings drop-down acquisition in excess of consideration paid 28,980 — Series A convertible preferred unit in-kind distribution and fair value adjustment — 6,301 Valley Wells' operating expense cap adjustment 518 — Purchase of assets in Holdings drop-down acquisition 62,640 — Net liabilities assumed by Holdings in Holdings drop-down acquisition 700 — Other — 1,688 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): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Total interest costs $ 8,531 $ 2,225 $ 16,406 $ 5,297 Capitalized interest included in property, plant and equipment, net (631 ) (454 ) (1,008 ) (553 ) Interest expense $ 7,900 $ 1,771 $ 15,398 $ 4,744 Deferred Financing 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 costs is included in other assets on the balance sheets. Changes in deferred financing costs are as follows (in thousands): 2015 2014 Deferred financing costs, January 1 $ 16,602 $ 5,237 Capitalization of deferred financing costs (1) 597 166 Amortization of deferred financing costs (1,557 ) (675 ) Deferred financing costs, June 30 $ 15,642 $ 4,728 (1) See Note 6. Southcross Assets Considered Leases to Third Parties In connection with the Onyx acquisition in March 2014, we acquired natural gas pipelines and contracts related to the acquired pipelines (see Note 2). The pipelines 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 agreements 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 June 30, 2015 were as follows: $2.8 million for the remainder of 2015; $5.6 million in 2016; $5.6 million in 2017; $2.2 million in 2018; $2.2 million in 2019; and $15.3 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 $0.7 million and $1.3 million for the three and six months ended June 30, 2015 and $0.7 million and $0.9 million for the three and six months ended June 30, 2014 , 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 $0.8 million and $1.5 million for the three and six months ended June 30, 2015 respectively. Variable fees recognized in revenues within transportation, gathering and processing fees were $0.3 million and $0.4 million for the three and six months ended June 30, 2014 , respectively.

EQUITY IN JOINT VENTURES

EQUITY IN JOINT VENTURES	6 Months Ended
	Jun. 30, 2015
Equity Method Investments and Joint Ventures [Abstract]
EQUITY IN JOINT VENTURES	INVESTMENTS IN JOINT VENTURES Assets acquired through the TexStar Rich Gas System Transaction include equity interests in three joint ventures. During 2012, a subsidiary of TexStar and a company subsequently acquired by Atlas Pipeline Partners, L.P. (“Atlas”) formed T2 Eagle Ford Gathering Company LLC (“T2 Eagle Ford”), T2 LaSalle Gathering Company LLC (“T2 LaSalle”) and T2 EF Cogeneration Holdings LLC (“T2 Cogen”) to construct and operate a pipeline and cogeneration facility located in South Texas. During 2015, Atlas was acquired by Targa, which is now our joint venture partner. We indirectly own a 50% interest in T2 Eagle Ford, a 50% interest in T2 Cogen and a 25% interest in T2 LaSalle. The joint ventures’ summarized financial data from their statements of operations for the three and six months ended June 30, 2015 is as follows (in thousands): Three Months Ended June 30, 2015 Six Months Ended June 30, 2015 T2 Eagle Ford T2 Cogen T2 LaSalle T2 Eagle Ford T2 Cogen T2 LaSalle Revenue $ 1,215 $ 1,187 $ 450 $ 2,136 $ 2,849 $ 829 Net loss (4,993 ) (1,492 ) (1,445 ) (9,975 ) (2,853 ) (2,965 ) Our equity in losses of joint venture investments is comprised of the following for the three and six months ended June 30, 2015 (in thousands): Three Months Ended June 30, 2015 Six Months Ended June 30, 2015 T2 Eagle Ford $ (2,496 ) $ (4,988 ) T2 Cogen (746 ) (1,426 ) T2 LaSalle (362 ) (741 ) Equity in losses of joint venture investments $ (3,604 ) $ (7,155 ) Our investments in joint ventures is comprised of the following as of June 30, 2015 (in thousands): Six Months Ended June 30, 2015 T2 Eagle Ford $ 104,817 T2 Cogen 18,740 T2 LaSalle 18,640 Investments in joint ventures $ 142,197

BASIS OF PRESENTATION AND SUM25

BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	6 Months Ended
	Jun. 30, 2015
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation We prepared this report under the rules and regulations of the Securities and Exchange Commission and in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim financial statements. Accordingly, these condensed consolidated financial statements do not include all of the disclosures required by GAAP and should be read in conjunction with our 2014 Annual Report on Form 10-K. The condensed consolidated financial statements as of June 30, 2015 and December 31, 2014 , and for the three and six months ended June 30, 2015 and 2014 , are unaudited and have been prepared on the same basis as the audited financial statements included in our 2014 Annual Report on Form 10-K. Adjustments (consisting of normal recurring adjustments) necessary for a fair presentation of the results of operations and financial position have been included herein. All intercompany accounts and transactions have been eliminated in the preparation of the accompanying condensed consolidated financial statements. The condensed consolidated financial statements reflect the assets acquired and liabilities assumed and the related operating results associated with (i) the Onyx pipelines acquisition beginning on March 6, 2014, (ii) the TexStar Rich Gas System Transaction and the 2015 Holdings Acquisition beginning on August 4, 2014, (iii) and the Texoz acquisition beginning on November 21, 2014. See Note 2. As a result of the Holdings Transaction, Holdings acquired a controlling equity interest in the Partnership, which was accounted for under the acquisition method of accounting in the consolidated financial statements of Holdings, whereby Holdings recorded the Partnership’s assets acquired and liabilities assumed at fair value. Additionally, because the TexStar Rich Gas System was owned by TexStar, the Partnership recorded the TexStar Rich Gas System at TexStar’s historical cost. Thus, the difference between consideration paid and the TexStar Rich Gas System’s historical cost (net book value) at August 4, 2014, the date on which the Holdings Transaction and the TexStar Rich Gas System Transaction closed, was recorded as a reduction to partners’ capital. Management concluded that the Partnership was the predecessor for accounting purposes for periods prior to August 4, 2014. We recognized the 2015 Holdings Acquisition 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 2. The accompanying unaudited condensed consolidated financial statements were prepared in conformity with GAAP, which 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 condensed consolidated financial statements and the reported amounts of revenues and expenses during the period. Actual results may differ from those estimates. Information for interim periods may not be indicative of our operating results for the entire year. The disclosures included in this report provide an update to our 2014 Annual Report on Form 10-K. 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.
Recent Accounting Pronouncements	Recent Accounting Pronouncements Accounting standard-setting organizations frequently issue new or revised accounting rules. We review and evaluate new pronouncements to determine their impact, if any, on our consolidated financial statements.

ACQUISITION (Tables)

ACQUISITION (Tables)	6 Months Ended
	Jun. 30, 2015
Business Combinations [Abstract]
Reconciliation of Fair Value of Assets Acquired and Liabilities Assumed	The fair value of the assets acquired and liabilities assumed related to the Onyx purchase price was as follows (in thousands): Purchase Price—Cash $ 38,636 Current assets $ 730 Property, plant and equipment 39,413 Total assets acquired 40,143 Current liabilities assumed (1,407 ) Other liabilities assumed (100 ) Net identifiable assets acquired $ 38,636
Schedule of Unaudited, Pro Forma Financial Information	The following unaudited pro forma financial information for the six months ended June 30, 2014 assumes that the acquisition of pipelines from Onyx occurred on January 1, 2013 and includes adjustments for income from operations, including depreciation and amortization, as well as the effects of financing the transaction (in thousands, except unit information): Six Months Ended June 30, 2014 Total revenue $ 409,303 Net loss (4,357 ) Net loss attributable to common unitholders (8,463 ) Net loss per common unit (basic and diluted) (0.43 ) Net loss attributable to subordinated unitholders (2,109 ) Net loss per subordinated unit (basic and diluted) (0.17 )

NET (LOSS) INCOME PER LIMITED27

NET (LOSS) INCOME PER LIMITED PARTNER UNIT AND DISTRIBUTIONS (Tables)	6 Months Ended
	Jun. 30, 2015
Net loss per limited partner unit and distributions
Schedule of Distributions Earned and Declared	The following table presents the PIK distribution earned on the Class B Convertible Units for periods after issuance on August 4, 2014 through June 30, 2015 (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) 2015 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 2014 February 13, 2015 December 31, 2014 0.3257 260,558 4,143 5,318 85 November 14, 2014 September 30, 2014 0.3257 256,078 5,467 5,226 112 (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. Cash Distributions The following table represents our distributions declared for the quarterly periods beginning in 2014 through the six months ended June 30, 2015 (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 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 2014 February 13, 2015 December 31, 2014 0.40 (1) 9,520 3,432 (2) 416 13,368 November 14, 2014 September 30, 2014 0.40 (1) 9,520 — 413 9,933 August 14, 2014 June 30, 2014 0.40 9,399 4,886 290 14,575 May 15, 2014 March 31, 2014 0.40 8,586 4,886 290 13,762 (1) The common unit distribution in the table above includes the distribution payment to the Series A Preferred unitholders for their Series A Preferred Units converted into common units or to the units that vested as part of our LTIP (as defined in Note 11) as a result of the Holdings Transaction (see Notes 1, 8 and 11). (2) Holdings waived the requirement that any distribution owed to it for the fourth quarter be paid within 45 days of the end of the quarter. We paid a distribution of $0.28 per unit on our 12,213,713 subordinated units in conjunction with the filing of our 2014 Annual Report on Form 10-K.
Schedule of Reconciliation of Net Income loss	The following is a reconciliation of the net loss attributable to our limited partners and our limited partner units and the basic and diluted earnings per unit calculations for the three and six months ended June 30, 2015 and 2014 (in thousands, except unit and per unit data): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Net loss $ (15,451 ) $ (2,961 ) $ (29,356 ) $ (4,249 ) Series A Preferred Unit fair value adjustment (1) — (5,062 ) — (5,029 ) Series A Preferred Unit in-kind distribution — (738 ) — (1,272 ) General partner Unit in-kind distribution (61 ) — (137 ) — Net loss attributable to Holdings (1,103 ) — (4,258 ) — Net loss attributable to partners $ (14,409 ) $ (8,761 ) $ (25,235 ) $ (10,550 ) General partner's interest (2) (306 ) (59 ) (561 ) (84 ) Class B Convertible limited partner interest (2) (3,981 ) — (7,100 ) — Limited partners' interest (2) Common (6,928 ) (7,382 ) (11,830 ) (8,398 ) Subordinated (3,194 ) (1,320 ) (5,744 ) (2,068 ) (1) The valuation adjustment to maximum redemption value of the Series A Preferred Unit in-kind distribution increased the net loss attributable to partners for the three and six months ended June 30, 2014 . (2) General Partner's and limited partners’ interests are calculated based on the allocation of net losses for the period, net of the allocation of Series A Preferred Unit in-kind distributions, Series A Preferred Unit fair value adjustments and General Partner Unit in-kind distributions. The Class B Convertible Unit interest is calculated based on the allocation of only net losses for the period. Three Months Ended June 30, Six Months Ended June 30, Common Units 2015 2014 2015 2014 Interest in net loss $ (6,928 ) $ (7,382 ) $ (11,830 ) $ (8,398 ) Effect of dilutive units - numerator (1) — — — — Dilutive interest in net loss $ (6,928 ) $ (7,382 ) $ (11,830 ) $ (8,398 ) Weighted-average units - basic 26,476,520 21,472,420 25,143,455 19,887,523 Effect of dilutive units - denominator (1) — — — Weighted-average units - dilutive 26,476,520 21,472,420 25,143,455 19,887,523 Basic and diluted net loss per common unit $ (0.26 ) $ (0.34 ) $ (0.47 ) $ (0.42 ) Three Months Ended June 30, Six Months Ended June 30, Subordinated Units 2015 2014 2015 2014 Interest in net loss $ (3,194 ) $ (1,320 ) $ (5,744 ) $ (2,068 ) Effect of dilutive units - numerator (1) — — — — Dilutive interest in net loss $ (3,194 ) $ (1,320 ) $ (5,744 ) $ (2,068 ) Weighted-average units - basic 12,213,713 12,213,713 12,213,713 12,213,713 Effect of dilutive units - denominator (1) — — — — Weighted-average units - dilutive 12,213,713 12,213,713 12,213,713 12,213,713 Basic and diluted net loss per subordinated unit $ (0.26 ) $ (0.11 ) $ (0.47 ) $ (0.17 ) (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 53,747 and 28,887 for the three and six months ended June 30, 2015 , respectively.
Preferred units issued
Net loss per limited partner unit and distributions
Schedule of Distributions Earned and Declared	The following table represents the paid in-kind (“PIK”) distribution declared in 2014 through August 4, 2014 , the date on which all outstanding Series A Preferred Units were converted to common units (in thousands, except per unit and in-kind distribution units): Payment Date Attributable to the Quarter Ended (1) Per Unit Distribution In-Kind Series A In-Kind Series A Distributions (2) In-Kind Unit to General Partner In-Kind General Partner Distribution Value (2) 2014 May 15, 2014 March 31, 2014 $ 0.40 31,513 $ 534 643 $ 11 (1) As a result of the conversion, the Series A Preferred Unit holders (and the corresponding General Partner units) ceased receiving PIK distributions effective with the quarter ended June 30, 2014, but received a cash distribution on the converted common units. (2) 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.

FINANCIAL INSTRUMENTS (Tables)

FINANCIAL INSTRUMENTS (Tables)	6 Months Ended
	Jun. 30, 2015
Derivatives
Schedule of Interest Rate Derivatives [Table Text Block]	Our interest rate swap position was as follows (in thousands): Estimated Fair Value Notional Amount Fixed Rate Effective Date Maturity Date June 30, 2015 $ 50,000 1.198 % September 30, 2014 June 30, 2016 $ (88 ) 50,000 1.196 % September 30, 2014 June 30, 2016 (88 ) 100,000 1.195 % June 30, 2015 January 1, 2017 (138 ) $ (314 )
Schedule of the fair value of the interest rate swap liabilities	The fair values of our interest rate derivatives were as follows (in thousands): Significant Other Observable Inputs (Level 2) Fair Value Measurement as of June 30, 2015 December 31, 2014 Current interest rate derivative assets $ 24 $ 27 Non-current interest rate derivative assets 20 27 Current interest rate derivative (liabilities) (268 ) (175 ) Non-current interest rate derivative (liabilities) (46 ) (39 ) Total interest rate derivatives $ (270 ) $ (160 )
Summary of amounts recognized in interest expense associated with derivatives that are not designated as hedging instruments	The realized and unrealized amounts recognized in interest expense associated with derivatives that are not designated as hedging instruments were as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Unrealized loss on interest rate derivatives $ 54 $ 168 $ 109 $ 180 Realized loss on interest rate derivatives 154 27 258 53
Interest rate cap contract
Derivatives
Summary of effect of cash flow hedge in statements of changes in partners' capital and members' equity and comprehensive income/(loss)
Commodity Swaps
Derivatives
Schedule of amounts recognized in the statement of operations	The effect of offsetting on our balance sheets was as follows (in thousands): June 30, 2015 December 31, 2014 Other Current Assets Other Current Liabilities Other Current Assets Other Current Liabilities Gross amounts of recognized assets $ — $ — $ 112 $ — Gross amounts offset on the balance sheets — — — — Net amount $ — $ — $ 112 $ — The realized and unrealized gain/loss on these derivatives, recognized in revenues in our statements of operations, was as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Realized gain (loss) on commodity swap derivatives $ 125 $ 81 $ 136 $ (1,088 ) Unrealized loss on commodity swap derivatives — (175 ) (112 ) (131 )

LONG-LIVED ASSETS (Tables)

LONG-LIVED ASSETS (Tables)	6 Months Ended
	Jun. 30, 2015
Property, Plant and Equipment [Abstract]
Schedule of property, plant and equipment	Property, plant and equipment consisted of the following (in thousands): Estimated Useful Life (yrs) June 30, 2015 December 31, 2014 Pipelines 15-30 $ 511,766 $ 488,592 Gas processing, treating and other plants 15 545,036 515,080 Compressors 7-15 69,082 62,741 Rights of way and easements 15 37,018 37,238 Furniture, fixtures and equipment 5 3,735 3,671 Capital lease vehicles 3-5 2,406 2,076 Total property, plant and equipment 1,169,043 1,109,398 Accumulated depreciation and amortization (176,809 ) (142,234 ) Total 992,234 967,164 Construction in progress 70,891 63,858 Land and other 24,372 27,548 Property, plant and equipment, net $ 1,087,497 $ 1,058,570

LONG-TERM DEBT (Tables)

LONG-TERM DEBT (Tables)	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
Schedule of Long-term Debt	Third A&R Revolving Credit Agreement The Third A&R Revolving Credit Agreement is a five -year $200 million revolving credit facility (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 increased to $75 million ; (b) we have the right to increase the total commitments under the Credit Facility by obtaining additional commitments from other lenders, as long as our senior secured leverage ratio is less than or equal to 4.50 to 1.00 before and after giving effect to such increase, subject to certain other conditions; (c) the definition of “Change of Control” is amended to permit the combination transaction with TexStar and to reflect the Sponsors’ control of the General Partner; (d) our maximum consolidated total leverage ratio (i) was set at 5.75 to 1.00 as of the last day of the fiscal quarter ending each of September 30, 2014 and December 31, 2014, (ii) is set at 5.50 to 1.00 as of the last day of the fiscal quarter ending March 31, 2015, (iii) 5.25 to 1.00 as of the last day of the fiscal quarter ending June 30, 2015 and (iv) 5.00 to 1.00 as of the last day of each fiscal quarter thereafter; (e) we had the right, exercisable on or before the date that our annual audited financial statements were due for the 2014 fiscal year, to comply with the consolidated total leverage ratio, consolidated senior secured leverage ratio and the consolidated interest coverage ratio covenants (the “Financial Covenants”) by applying certain specified quarterly base periods and annualization methods pertaining to the TexStar Rich Gas System; (f) if we fail to comply with the Financial Covenants (a “Financial Covenant Default”), we have the right (which cannot be exercised more than two times in any twelve month period or more than four times during the term of the facility) 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; (g) certain definitions are amended to take into account the TexStar Rich Gas System; and (h) the negative covenants are amended to permit the entry into, and indebtedness under, the Term Loan Agreement. Amendment to Third A&R Revolving Credit Agreement During the fourth quarter of 2014 and into the first quarter of 2015 , as a result of the decline in commodity prices and associated decline in upstream drilling activity, we experienced a decline in the growth in volume of natural gas we gather and process for our customers. Our results in the first quarter of 2015 were also negatively impacted by the fire at our Gregory facility (see Note 5). These collective events impacted our operating results adversely and resulted in the need to amend our Third A&R Revolving Credit Agreement. On May 7, 2015, we entered into a First Amendment to our Third A&R Revolving Credit Agreement among the Partnership, as the borrower, Wells Fargo, N.A., as the administrative agent, the lenders and other parties thereto (the “Credit Agreement Amendment”). The Credit Agreement Amendment amended the Third A&R Revolving Credit Agreement. The Credit Agreement Amendment, among other things: (a) (i) revised the maximum consolidated total leverage ratio set at 5.75 to 1.0 as of the last day of the fiscal quarter ending each of March 31, 2015, June 30, 2015 and September 30, 2015, (ii) 5.5 to 1.0 as of the last day of the fiscal quarter ending each of December 31, 2015, March 31, 2016 and June 30, 2016, (iii) 5.25 to 1.0 as of the last day of the fiscal quarter ending September 30, 2016, and (iv) 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; (b) 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% ; (c) permits the Partnership to comply with certain Financial Covenants by making certain pro forma adjustments with respect to minimum revenues to be received from Frio; (d) modified our ability to cure Financial Covenant defaults; (e) imposed additional restrictions on our ability to declare and pay quarterly cash distributions with respect to our subordinated units; (f) amended certain other provisions of the Third A&R Revolving Credit Agreement as more specifically set forth in the Credit Agreement Amendment; and (g) allows 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. Additionally, we are unable to borrow on our Credit Facility until we have funded the required equity cure for the second quarter of 2015; however, we retain the ability to fund the required equity cure using a contractual non-cash credit amount of up to $13 million . Term Loan Agreement The Term Loan Agreement is a seven-year $450 million senior secured term loan facility. On August 4, 2014 , the lenders funded the full amount of the facility. 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% . Under the Term Loan Agreement, among other things: (a) subject to certain requirements, including the absence of a default and pro forma compliance under the Third A&R Revolving Credit Agreement and pro forma compliance with a senior secured leverage ratio less than or equal to 4.50 to 1.00 before and after giving effect to such increase, we may from time to time request incremental term loan commitments subject to certain other conditions; (b) we may seek commitments from third party lenders in connection with any incremental term loan commitment requests, subject to certain consent rights given to the administrative agent; (c) the guarantors and the collateral are the same as provided for the benefits of the lenders in the Third A&R Revolving Credit Agreement; (d) subject to certain conditions, we may request that the lenders extend the seven -year maturity of all or a portion of the outstanding loans under the facility; (e) the facility will amortize 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; (f) there are customary mandatory prepayment provisions and, subject to certain conditions, permissive prepayment provisions; provided, that if certain repricing transactions occur, we must pay a call premium equal to 1% of the principal amount of the loans subject to the repricing transactions; and (g) there are customary representations and warranties, affirmative covenants, negative covenants and provisions governing an event of default (including acceleration of payment in connection with material indebtedness, including the Third A&R Revolving Credit Agreement).

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	6 Months Ended
	Jun. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Schedule of Capital Lease Obligations	he capital lease obligation amounts included on the balance sheets were as follows (in thousands): June 30, 2015 December 31, 2014 Other current liabilities $ 435 $ 455 Other non-current liabilities 664 578 Total $ 1,099 $ 1,033

TRANSACTIONS WITH RELATED PAR32

TRANSACTIONS WITH RELATED PARTIES (Tables)	6 Months Ended
	Jun. 30, 2015
Related Party Transactions [Abstract]
Schedule of Fees, Expenses and Reimbursements Incurred Through Services with Related Parties	We incurred fees and expenses related to the services from our affiliated directors as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Charlesbank $ 42 $ 110 $ 80 $ 215 EIG 17 — 33 — Tailwater 17 — 33 — Total fees and expenses paid for director services to affiliated entities $ 76 $ 110 $ 146 $ 215 We incurred expenses related to these reimbursements as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Reimbursements included in general and administrative expenses $ 3,845 $ 3,576 $ 7,080 $ 7,051 Reimbursements included in operations and maintenance expenses 5,133 4,113 10,432 8,056 Total reimbursements to our General Partner and its affiliates $ 8,978 $ 7,689 $ 17,512 $ 15,107

INCENTIVE COMPENSATION (Tables)

INCENTIVE COMPENSATION (Tables)	6 Months Ended
	Jun. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of information regarding awards of units granted under the Incentive Plan	The following table summarizes information regarding awards of units granted under the LTIP:
Summary of information regarding recognized compensation expense, which is included in general and administrative expense on consolidated statements of operations	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): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Unit-based compensation $ 1,662 $ 1,082 $ 2,475 $ 1,611
Schedule of employer 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): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Matching contributions expensed for employee savings plan $ 172 $ 234 $ 340 $ 590

REVENUES (Tables)

REVENUES (Tables)	6 Months Ended
	Jun. 30, 2015
Revenues [Abstract]
Schedule of revenues by category	We had revenues consisting of the following categories (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Sales of natural gas $ 92,518 $ 123,401 $ 205,304 $ 268,759 Sales of NGLs and condensate 39,427 54,282 76,610 106,155 Transportation, gathering and processing fees 33,823 17,279 68,876 33,394 Other 1,452 101 2,368 346 Total revenues $ 167,220 $ 195,063 $ 353,158 $ 408,654

CONCENTRATION OF CREDIT RISK 35

CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE (Tables)	6 Months Ended
	Jun. 30, 2015
Consolidated revenue concentration
Schedule of consolidated revenue attributed to Formosa and Sherwin	The percentage of total consolidated revenue for each customer that exceeded 10% of total revenues for the three and six months ended June 30, 2015 and 2014 was as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Sherwin Alumina Company (a) 12.2 % (a) 11.0 % Trafigura AG 13.0 % 13.0 % 11.8 % 12.6 % (a) Information is not provided for periods for which the customer or producer was less than 10% of our consolidated revenue.
Top ten customers
Consolidated revenue concentration
Schedule of consolidated revenue attributed to Formosa and Sherwin	Our top ten customers for the three and six months ended June 30, 2015 and 2014 represent the following percentages of consolidated revenue: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Top ten customers 55.8 % 73.0 % 56.8 % 68.6 %

SUPPLEMENTAL INFORMATION (Table

SUPPLEMENTAL INFORMATION (Tables)	6 Months Ended
	Jun. 30, 2015
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information (in thousands) Six Months Ended June 30, 2015 2014 Supplemental Disclosures: Cash paid for interest, net of amounts capitalized $ 14,221 $ 4,200 Cash received for tax refunds 58 185 Supplemental disclosures of non-cash investing and financing activities: Accounts payable related to capital expenditures 9,615 9,656 Change in value recognized in other comprehensive loss — 11 Capital lease obligations 342 466 Accrued distribution equivalent rights on LTIP units 444 259 Class B Convertible unit in-kind distributions 6,706 — Net assets contributed in Holdings drop-down acquisition in excess of consideration paid 28,980 — Series A convertible preferred unit in-kind distribution and fair value adjustment — 6,301 Valley Wells' operating expense cap adjustment 518 — Purchase of assets in Holdings drop-down acquisition 62,640 — Net liabilities assumed by Holdings in Holdings drop-down acquisition 700 — Other — 1,688
Capitalization of Interest Cost	We incurred the following interest costs (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Total interest costs $ 8,531 $ 2,225 $ 16,406 $ 5,297 Capitalized interest included in property, plant and equipment, net (631 ) (454 ) (1,008 ) (553 ) Interest expense $ 7,900 $ 1,771 $ 15,398 $ 4,744
Deferred Financing Costs	Changes in deferred financing costs are as follows (in thousands): 2015 2014 Deferred financing costs, January 1 $ 16,602 $ 5,237 Capitalization of deferred financing costs (1) 597 166 Amortization of deferred financing costs (1,557 ) (675 ) Deferred financing costs, June 30 $ 15,642 $ 4,728 (1) See Note 6.

EQUITY IN JOINT VENTURES (Table

EQUITY IN JOINT VENTURES (Tables)	6 Months Ended
	Jun. 30, 2015
Equity Method Investments and Joint Ventures [Abstract]
Schedules of joint ventures	The joint ventures’ summarized financial data from their statements of operations for the three and six months ended June 30, 2015 is as follows (in thousands): Three Months Ended June 30, 2015 Six Months Ended June 30, 2015 T2 Eagle Ford T2 Cogen T2 LaSalle T2 Eagle Ford T2 Cogen T2 LaSalle Revenue $ 1,215 $ 1,187 $ 450 $ 2,136 $ 2,849 $ 829 Net loss (4,993 ) (1,492 ) (1,445 ) (9,975 ) (2,853 ) (2,965 ) Our equity in losses of joint venture investments is comprised of the following for the three and six months ended June 30, 2015 (in thousands): Three Months Ended June 30, 2015 Six Months Ended June 30, 2015 T2 Eagle Ford $ (2,496 ) $ (4,988 ) T2 Cogen (746 ) (1,426 ) T2 LaSalle (362 ) (741 ) Equity in losses of joint venture investments $ (3,604 ) $ (7,155 ) Our investments in joint ventures is comprised of the following as of June 30, 2015 (in thousands): Six Months Ended June 30, 2015 T2 Eagle Ford $ 104,817 T2 Cogen 18,740 T2 LaSalle 18,640 Investments in joint ventures $ 142,197

ORGANIZATION AND DESCRIPTION 38

ORGANIZATION AND DESCRIPTION OF BUSINESS (Details) $ in Millions	Aug. 22, 2015	Aug. 04, 2014	Jun. 30, 2015USD ($)segmentplant
Business Acquisition [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest			2.00%
Noncash Investing and Financing Transactions, Other			$ 4.7
Other Additional Capital			$ 25
Number of fractionation plants | plant			2
Number of reportable segments | segment			1
Noncash or Part Noncash Acquisition, Investments Acquired			$ 13
Southcross Holdings Common [Member]
Business Acquisition [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest		100.00%
Subsequent Event [Member]
Business Acquisition [Line Items]
Investment Contract Settlement Date Range End	15 days

ACQUISITION (Details)

ACQUISITION (Details)	May. 08, 2015USD ($)	May. 07, 2015USD ($)$ / shares	Aug. 04, 2014USD ($)$ / shares	Mar. 08, 2014	Mar. 06, 2014USD ($)plant	Mar. 31, 2014USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)$ / shares	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Nov. 21, 2014USD ($)
Business Acquisition [Line Items]
Total revenues							$ 167,220,000	$ 195,063,000	$ 353,158,000	$ 408,654,000
Business Acquisition, Pro Forma Revenue							165,560,000		346,109,000
Revenue from Related Parties							$ 21,091,000	0	28,538,000	0
Payments to Acquire Businesses, Gross		$ 77,600,000							$ 80,000,000
Shares Issued, Price Per Share | $ / shares			$ 22.17
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities			$ 100,000,000
Number of power plants					2		2		2
Contractual agreement, term				10 years	10 years
Fair Value of Assets Acquired and Liabilities Assumed, Net [Abstract]
Net identifiable assets acquired							$ 0		$ 0
Payments to Acquire Businesses, Net of Cash Acquired		$ 15,000,000							0	38,636,000
Business Acquisition, Pro Forma Information [Abstract]
Revenue recognized since acquisition date							800,000	300,000	1,500,000	400,000
Business Combination, Consideration Transferred	$ 28,980,000		98,625,000						15,000,000
Business Acquisition, Pro Forma Net Income (Loss)							(14,348,000)		(25,098,000)
Net loss							(15,451,000)	(2,961,000)	(29,356,000)	$ (4,249,000)
Business Acquisition, Share Price | $ / shares		$ 13.92
TexStar Rich Gas System [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net			404,414,000
Fair Value of Assets Acquired and Liabilities Assumed, Net [Abstract]
Current assets			1,295,000
Property, plant, and equipment			255,220,000
Noncontrolling Interest in Joint Ventures			152,050,000
Total assets acquired			408,565,000
Net identifiable assets acquired			305,789,000
Goodwill			98,625,000
Business Acquisition, Pro Forma Information [Abstract]
Business Combination, Liabilities Arising from Contingencies, Amount Recognized			(102,776,000)
Pipelines [Member]
Fair Value of Assets Acquired and Liabilities Assumed, Net [Abstract]
Net identifiable assets acquired			100,000,000
TexStar Rich Gas System [Member]
Business Acquisition [Line Items]
Revenue from Related Parties							1,660,000		7,049,000
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net	77,640,000
Fair Value of Assets Acquired and Liabilities Assumed, Net [Abstract]
Total assets acquired	106,620,000
Business Acquisition, Pro Forma Information [Abstract]
Business Combination, Consideration Transferred	14,442,000
Related Party Transaction, Other Revenues from Transactions with Related Party							(1,103,000)		(4,258,000)
Business Combination, Bargain Purchase, Gain Recognized, Amount	28,980,000
Onyx Midstream LP & Onyx Pipeline Company [Member]
Fair Value of Assets Acquired and Liabilities Assumed, Net [Abstract]
Current assets					$ 730,000
Property, plant, and equipment					39,413,000
Total assets acquired					40,143,000
Current liabilities assumed					(1,407,000)
Other liabilities assumed					(100,000)
Net identifiable assets acquired					$ 38,636,000
Goodwill							0		0
Onyx Midstream LP & Onyx Pipeline Company [Member] | Pro Forma [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue						$ 1,600,000		409,303,000
Business Acquisition, Pro Forma Information [Abstract]
Business Acquisition, Pro Forma Net Income (Loss)						$ 300,000		(4,357,000)
Onyx Midstream LP & Onyx Pipeline Company [Member] | Common Units [Member] | Pro Forma [Member]
Business Acquisition, Pro Forma Information [Abstract]
Business Acquisition, Pro Forma Net Income (Loss)								$ (8,463,000)
Business Acquisition, Pro Forma Earnings Per Share, Basic and Diluted | $ / shares								$ (0.43)
Onyx Midstream LP & Onyx Pipeline Company [Member] | Subordinated Units [Member] | Pro Forma [Member]
Business Acquisition, Pro Forma Information [Abstract]
Business Acquisition, Pro Forma Net Income (Loss)								$ (2,109,000)
Business Acquisition, Pro Forma Earnings Per Share, Basic and Diluted | $ / shares								$ (0.17)
Texoz [Member]
Fair Value of Assets Acquired and Liabilities Assumed, Net [Abstract]
Net identifiable assets acquired											$ 5,400,000
Common Limited Partners [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities							0		0
Fair Value of Assets Acquired and Liabilities Assumed, Net [Abstract]
Net identifiable assets acquired							14,442,000		14,442,000
Business Acquisition, Pro Forma Information [Abstract]
Business Combination, Consideration Transferred			45,420,000						62,640,000
Class B Convertible Units [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities							0		0
Fair Value of Assets Acquired and Liabilities Assumed, Net [Abstract]
Net identifiable assets acquired							7,728,000		7,728,000
Business Acquisition, Pro Forma Information [Abstract]
Business Combination, Consideration Transferred			27,925,000						0
Net loss							(3,981,000)		(7,100,000)
Class B Convertible Units [Member] | TexStar Rich Gas System [Member]
Business Acquisition, Pro Forma Information [Abstract]
Business Combination, Consideration Transferred	$ 7,728,000
Subordinated Limited Partners [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities							0		0
Fair Value of Assets Acquired and Liabilities Assumed, Net [Abstract]
Net identifiable assets acquired							6,231,000		6,231,000
Business Acquisition, Pro Forma Information [Abstract]
Business Combination, Consideration Transferred									0
Subordinated Limited Partners [Member] | TexStar Rich Gas System [Member]
Business Acquisition, Pro Forma Information [Abstract]
Business Combination, Consideration Transferred			23,308,000
Subordinated Limited Partners [Member] | TexStar Rich Gas System [Member]
Business Acquisition, Pro Forma Information [Abstract]
Business Combination, Consideration Transferred			6,231,000
General Partner [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities							0		0
Fair Value of Assets Acquired and Liabilities Assumed, Net [Abstract]
Net identifiable assets acquired							579,000		579,000
Business Acquisition, Pro Forma Information [Abstract]
Business Combination, Consideration Transferred									0
Net loss							$ (306,000)	$ (59,000)	$ (561,000)
General Partner [Member] | TexStar Rich Gas System [Member]
Business Acquisition, Pro Forma Information [Abstract]
Business Combination, Consideration Transferred			1,972,000
General Partner [Member] | TexStar Rich Gas System [Member]
Business Acquisition, Pro Forma Information [Abstract]
Business Combination, Consideration Transferred			$ 579,000

NET (LOSS) INCOME PER LIMITED40

NET (LOSS) INCOME PER LIMITED PARTNER UNIT AND DISTRIBUTIONS (Details) - USD ($) $ / shares in Units, $ in Thousands	Aug. 04, 2014	Apr. 12, 2013	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Earnings Per Limited Partner Unit
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount			53,747	28,887
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest					2.00%
Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure						$ 0
Net loss attributable to partners			$ (14,409)	$ (8,761)	$ (25,235)	(10,550)
General partner's interest			$ (15,451)	(2,961)	(29,356)	(4,249)
Limited partners' interest					$ (29,356)	(4,249)
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit			$ 0.40
General Partner [Member]
Earnings Per Limited Partner Unit
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	2.00%				2.00%
Net Income (Loss) Allocated to General Partners					$ (502)	(84)
Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure			$ (61)	0	(137)
General partner's interest			(306)	(59)	(561)
Limited partners' interest						(85)
Southcross Holdings Common [Member]
Earnings Per Limited Partner Unit
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	100.00%
Net loss attributable to partners			(1,103)	0	(4,258)	0
Class B Convertible Units [Member]
Earnings Per Limited Partner Unit
General partner's interest			(3,981)		(7,100)
Limited partners' interest					(7,100)
Limited Partner, units authorized
Earnings Per Limited Partner Unit
Limited partners' interest			(6,928)	(7,382)	(11,830)	(8,398)
Interest in net loss			(6,928)	(7,382)	(11,830)	(8,398)
Dilutive interest in net loss			$ (6,928)	$ (7,382)	$ (11,830)	$ (8,398)
Weighted-average units - basic			26,476,520	21,472,420	25,143,455	19,887,523
Weighted-average units - dilutive			26,476,520	21,472,420	25,143,455	19,887,523
Basic and diluted net loss per common unit			$ (0.26)	$ (0.34)	$ (0.47)	$ (0.42)
Subordinated Units [Member]
Earnings Per Limited Partner Unit
Limited partners' interest			$ (3,194)	$ (1,320)	$ (5,744)	$ (2,068)
Interest in net loss			(3,194)	(1,320)	(5,744)	(2,068)
Dilutive interest in net loss			$ (3,194)	$ (1,320)	$ (5,744)	$ (2,068)
Weighted-average units - basic			12,213,713	12,213,713	12,213,713	12,213,713
Weighted-average units - dilutive			12,213,713	12,213,713	12,213,713	12,213,713
Basic and diluted net loss per common unit			$ (0.26)	$ (0.11)	$ (0.47)	$ (0.17)
Class B Convertible Units [Member]
Earnings Per Limited Partner Unit
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit			0.3257
Distribution Made to Member or Limited Partner Minimum Annual Distributions Declared Per Unit			$ 1.60
Common Units [Member] | Limited Partner, units authorized
Earnings Per Limited Partner Unit
Limited partners' interest				$ (7,382)
Preferred units issued
Earnings Per Limited Partner Unit
Preferred Units, Issued		1,715,000
Preferred unit Conversion Common Units Exchange Ratio on Satisfaction of Specified Condition		110.00%
Number of Common Units to be Issued on Conversion of One Preferred Unit			2,015,638
Dividends, Preferred Stock, Paid-in-kind			$ 0	$ (738)	$ 0	$ (1,272)
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit					$ 0.40
Preferred units issued | General Partner [Member]
Earnings Per Limited Partner Unit
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest					2.00%

NET (LOSS) INCOME PER LIMITED41

NET (LOSS) INCOME PER LIMITED PARTNER UNIT AND DISTRIBUTIONS (Distributions) (Details)	Aug. 04, 2014	May. 15, 2013shares	Apr. 12, 2013shares	Jun. 30, 2015USD ($)item$ / shares	Mar. 31, 2015USD ($)$ / shares	Dec. 31, 2014USD ($)$ / shares	Sep. 30, 2014USD ($)$ / shares	Jun. 30, 2014USD ($)$ / sharesshares	Mar. 31, 2014USD ($)	Jun. 30, 2015USD ($)$ / shares	Jun. 30, 2014USD ($)	Mar. 05, 2015shares	Mar. 13, 2014USD ($)	Mar. 27, 2013USD ($)	Nov. 07, 2012USD ($)
Distributions made to Limited Partner [Line Items]
Ownership interest held by general partners (as a percent)										2.00%
Series A preferred units , PIK distribution earned
In-Kind Distributions (in dollars per unit)											$ 0
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit | $ / shares				$ 0.40
Subordinated Units [Member]
Common units, distribution declared and paid
Shares, Outstanding | shares												12,213,713
General Partner [Member]
Distributions made to Limited Partner [Line Items]
Ownership interest held by general partners (as a percent)	2.00%									2.00%
Series A preferred units , PIK distribution earned
In-Kind Distributions (in dollars per unit)				$ 61,000				$ 0		$ 137,000
Series A Convertible Preferred Units [Member]
Distributions made to Limited Partner [Line Items]
Amount raised through issuance of units								$ 40,000,000
Preferred Units, Issued | shares			1,715,000
Preferred units issued | shares		248,675	1,466,325					1,500,000
Number of quarters for quarterly distributions in-kind required to be paid | item				4
Series A preferred units , PIK distribution earned
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit | $ / shares										$ 0.40
Series A Convertible Preferred Units [Member] | General Partner [Member]
Distributions made to Limited Partner [Line Items]
Ownership interest held by general partners (as a percent)										2.00%
PIK distribution | Series A Convertible Preferred Units [Member]
Distributions made to Limited Partner [Line Items]
Distribution percentage										7.00%
In Kind Distribution [Member] | Series A Convertible Preferred Units [Member]
Series A preferred units , PIK distribution earned
Distribution Made to Member or Limited Partner Unit Distributions Per Unit | $ / shares				$ 0.40
In-Kind Unit Distribution (in dollars)				$ 31,513,000
In-Kind Distributions (in dollars per unit)				534,000
In Kind Distribution [Member] | Series A Convertible Preferred Units [Member] | General Partner [Member]
Series A preferred units , PIK distribution earned
In-Kind Unit Distribution (in dollars)				643,000
In-Kind Distributions (in dollars per unit)				11,000
In Kind Distribution [Member] | Preferred units issued
Series A preferred units , PIK distribution earned
In-Kind Unit Distribution (in dollars)				269,758,000	$ 265,118,000	$ 260,558,000	$ 256,078,000
In-Kind Distributions (in dollars per unit)				2,994,000	3,712,000	4,143,000	5,467,000	$ 0		$ 6,706,000
In Kind Distribution [Member] | Preferred units issued | General Partner [Member]
Series A preferred units , PIK distribution earned
In-Kind Unit Distribution (in dollars)				5,505,000	5,410,000	5,318,000	5,226,000
In-Kind Distributions (in dollars per unit)				$ 61,000	$ 76,000	$ 85,000	$ 112,000
Cash
Series A preferred units , PIK distribution earned
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				$ 0.4		$ 0.4		$ 0.4
Common units, distribution declared and paid
Distribution Made to Member or Limited Partner, Distribution Paid in Cash				$ 11,782,000	$ 9,938,000	$ 13,368,000	$ 9,933,000	$ 14,575,000	$ 13,762,000
Cash | General Partner [Member]
Common units, distribution declared and paid
Distribution Made to Member or Limited Partner, Distribution Paid in Cash				457,000	418,000	416,000	413,000	290,000
Cash | Limited Partner, units authorized | Limited Partners
Common units, distribution declared and paid
Distribution Made to Member or Limited Partner, Distribution Paid in Cash				$ 11,325,000	9,520,000	9,520,000	9,520,000	$ 9,399,000	$ 8,586,000
Cash | Subordinated Units [Member] | Limited Partners
Series A preferred units , PIK distribution earned
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit | $ / shares				$ 0.40				$ 0.40
Common units, distribution declared and paid
Distribution Made to Member or Limited Partner, Distribution Paid in Cash				$ 0	$ 0	3,432,000	$ 0	$ 4,886,000		$ 0	$ 0
Cash | Subordinated Units [Member]
Common units, distribution declared and paid
Distribution Made to Member or Limited Partner, Distribution Paid in Cash						$ 0.28
Maximum [Member] | Cash
Distributions made to Limited Partner [Line Items]
Distribution period										45 days
Credit Facility, due November 2017
Distributions made to Limited Partner [Line Items]
unused borrowings													$ (350,000,000)	$ (250,000,000)	$ (350,000,000)

FINANCIAL INSTRUMENTS (Details)

FINANCIAL INSTRUMENTS (Details)	1 Months Ended	3 Months Ended		6 Months Ended		12 Months Ended
	Feb. 28, 2014USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Dec. 31, 2013MMBTU	Dec. 31, 2014USD ($)
Fair value of financial instruments
Unrealized Gain (Loss) on Derivatives				$ (221,000)	$ (312,000)
Repayments of Lines of Credit	$ 148,500,000
Derivative liability, non-current		$ 46		46			$ 39
Fair value measurement		(270)		(270)			(160)
Derivative, Fair Value, Net		44		44
Interest Rate Swap 0.327% [Member]
Fair value of financial instruments
Derivative, Notional Amount			$ 50,000,000		$ 50,000,000
Derivative, Fixed Interest Rate			1.1975%		1.1975%
Commodity Swaps [Member]
Fair value of financial instruments
Gain (Loss) on Sale of Derivatives		125,000	$ 81,000	136,000	$ (1,088,000)
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU						12,000
Unrealized Gain (Loss) on Derivatives		0	(175,000)	(112,000)	(131,000)
Interest Rate Cap [Member]
Fair value of financial instruments
Gain (Loss) on Sale of Derivatives		54,000	168,000	109,000	180,000
Unrealized Gain (Loss) on Derivatives		$ 154,000	27,000	$ 258,000	53,000
Interest Rate Swap 1.198% [Member]
Fair value of financial instruments
Derivative, Notional Amount			50,000,000		50,000,000
Derivative, Fixed Interest Rate		1.196%		1.196%
Interest Rate Swap 1.196% [Member]
Fair value of financial instruments
Derivative, Notional Amount		$ 100,000,000		$ 100,000,000
Derivative, Fixed Interest Rate		1.195%		1.195%
Fair Value, Measurements, Recurring [Member] | Interest Rate Swap 0.327% [Member]
Fair value of financial instruments
Derivative Liability, Fair Value, Gross Asset		$ 88		$ 88
Fair Value, Measurements, Recurring [Member] | Interest Rate Swap 1.198% [Member]
Fair value of financial instruments
Derivative Liability, Fair Value, Gross Asset		88		88
Fair Value, Measurements, Recurring [Member] | Interest Rate Swap 1.196% [Member]
Fair value of financial instruments
Derivative Liability, Fair Value, Gross Asset		138		138
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) | Interest rate swap liabilities
Fair value of financial instruments
Derivative Asset		24,000		24,000			27,000
Fair value measurement		0		0			$ 0
Designated as Hedging Instrument [Member] | Interest rate swap liabilities
Fair value of financial instruments
Derivative, Notional Amount		$ 150,000,000		150,000,000
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred				$ (100,000)
Derivative, Description of Variable Rate Basis				one-month London Interbank Offered Rate (“LIBOR”)
Derivative, Fixed Interest Rate		0.54%		0.54%
Designated as Hedging Instrument [Member] | Interest Rate Cap [Member]
Fair value of financial instruments
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net			0		(11,000)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net			$ 106,000		$ 221,000

FINANCIAL INSTRUMENTS (Details

FINANCIAL INSTRUMENTS (Details 2)	1 Months Ended	3 Months Ended		6 Months Ended		12 Months Ended
	Feb. 28, 2014USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Dec. 31, 2013MMBTU	Dec. 31, 2014USD ($)
Derivatives
Derivative Asset, Noncurrent		$ 20		$ 20			$ 27,000
Derivative Liability		(314)		(314)
Derivative Liability, Noncurrent		(46)		(46)			(39)
Repayments of Lines of Credit	$ 148,500,000
Unrealized loss				(221,000)	$ (312,000)
Derivative, Fair Value, Net		44		44
Derivative Liability		270		270			160
Interest Rate Cap 1.500% [Member]
Derivatives
Notional amount							$ 20,000,000
Derivative, Cap Interest Rate							1.50%
Interest Rate Swap [Member] | Derivatives designated as hedging instruments
Derivatives
Notional amount		$ 150,000,000		$ 150,000,000
LIBOR based fixed rate paid (as a percent)		0.54%		0.54%
Estimated amount of hedging losses to be reclassified from accumulated other comprehensive income into income/(loss)				$ 100,000
Interest Rate Swap 0.327% [Member]
Derivatives
Notional amount			$ 50,000,000		$ 50,000,000
LIBOR based fixed rate paid (as a percent)			1.1975%		1.1975%
Interest Rate Swap 1.198% [Member]
Derivatives
Notional amount			$ 50,000,000		$ 50,000,000
LIBOR based fixed rate paid (as a percent)		1.196%		1.196%
Interest rate cap contract
Derivatives
Unrealized loss		$ 154,000	27,000	$ 258,000	53,000
Realized (loss) on derivatives		54,000	168,000	109,000	180,000
Interest rate cap contract | Derivatives designated as hedging instruments
Derivatives
Change in value recognized in other comprehensive income/(loss) (effective portion)			0		(11,000)
Loss reclassified from accumulated other comprehensive loss to income/loss			106,000		221,000
Interest rate swap contract
Derivatives
Notional amount		$ 100,000,000		$ 100,000,000
LIBOR based fixed rate paid (as a percent)		1.195%		1.195%
Commodity Swaps
Derivatives
Unrealized loss		$ 0	(175,000)	$ (112,000)	(131,000)
Realized (loss) on derivatives		125,000	$ 81,000	136,000	$ (1,088,000)
Volume of month-ahead swap contracts (in MMBtu) | MMBTU						12,000
Interest Rate Cap 3.00% [Member]
Derivatives
Notional amount		$ 80,000,000		$ 80,000,000
Derivative, Cap Interest Rate		3.00%		3.00%
Other Current Assets | Commodity Swaps
Derivatives
Derivative Asset, Fair Value, Gross Asset		$ 0		$ 0			$ 112,000
Derivative Liability, Fair Value, Gross Liability							0
Derivative, Fair Value, Net		0		0			112,000
Other Current Liabilities | Commodity Swaps
Derivatives
Derivative Liability, Fair Value, Gross Liability		0		0			0
Derivative Liability, Amount Offset Against Derivative Asset		0		0			0
Derivative, Fair Value, Net		0		0			0
Fair Value, Measurements, Recurring [Member] | Interest Rate Cap 1.500% [Member]
Derivatives
Derivative Liability, Fair Value, Gross Asset		12		12
Fair Value, Measurements, Recurring [Member] | Interest Rate Swap 0.327% [Member]
Derivatives
Derivative Liability, Fair Value, Gross Asset		88		88
Fair Value, Measurements, Recurring [Member] | Interest Rate Swap 1.198% [Member]
Derivatives
Derivative Liability, Fair Value, Gross Asset		88		88
Fair Value, Measurements, Recurring [Member] | Interest rate swap contract
Derivatives
Derivative Liability, Fair Value, Gross Asset		138		138
Fair Value, Measurements, Recurring [Member] | Interest Rate Cap 3.00% [Member]
Derivatives
Derivative Liability, Fair Value, Gross Asset		32		32
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Interest Rate Swap [Member]
Derivatives
Derivative Asset		24,000		24,000			27,000
Derivative Liability		$ 0		$ 0			$ 0

LONG-LIVED ASSETS (Details)

LONG-LIVED ASSETS (Details) - USD ($)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2012	Dec. 31, 2014	Mar. 31, 2013
Property, plant and equipment
Total property, plant and equipment	$ 1,169,043,000		$ 1,169,043,000			$ 1,109,398,000
Accumulated depreciation and amortization	(176,809,000)		(176,809,000)			(142,234,000)
Property, plant and equipment, net	1,087,497,000		1,087,497,000			1,058,570,000
Depreciation expense	17,571,000	$ 8,978,000	34,603,000	$ 17,506,000
Intangible assets, net	1,483,000		$ 1,483,000			1,511,000	$ 1,554,211
Finite-Lived Intangible Asset, Useful Life			30 years
Property, plant and equipment excluding construction in progress and land and other
Property, plant and equipment
Property, plant and equipment, net	992,234,000		$ 992,234,000			967,164,000
Pipelines
Property, plant and equipment
Estimated useful life			30 years		30 years
Total property, plant and equipment	511,766,000		$ 511,766,000			488,592,000
Gas processing, treating and other plants
Property, plant and equipment
Estimated useful life			15 years		15 years
Total property, plant and equipment	545,036,000		$ 545,036,000			515,080,000
Compressors
Property, plant and equipment
Estimated useful life			7 years		7 years
Total property, plant and equipment	69,082,000		$ 69,082,000			62,741,000
Rights of way and easements
Property, plant and equipment
Estimated useful life			15 years		15 years
Total property, plant and equipment	37,018,000		$ 37,018,000			37,238,000
Furniture, fixtures and equipment
Property, plant and equipment
Estimated useful life			5 years		5 years
Total property, plant and equipment	3,735,000		$ 3,735,000			3,671,000
Capital lease vehicles
Property, plant and equipment
Total property, plant and equipment	2,406,000		$ 2,406,000			2,076,000
Capital lease vehicles | Maximum [Member]
Property, plant and equipment
Estimated useful life			5 years
Capital lease vehicles | Minimum [Member]
Property, plant and equipment
Estimated useful life			3 years
Construction in progress
Property, plant and equipment
Property, plant and equipment, net	70,891,000		$ 70,891,000			63,858,000
Land and other
Property, plant and equipment
Property, plant and equipment, net	$ 24,372,000		$ 24,372,000			$ 27,548,000

LONG-TERM DEBT (Details)

LONG-TERM DEBT (Details)	Aug. 04, 2014USD ($)	Nov. 30, 2012	Dec. 31, 2016	Sep. 30, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015USD ($)	Mar. 31, 2015	Sep. 30, 2014	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)$ / shares	Jun. 30, 2014USD ($)	Sep. 30, 2012	Dec. 31, 2014USD ($)	Mar. 13, 2014USD ($)	Mar. 27, 2013USD ($)	Nov. 07, 2012USD ($)
LONG TERM DEBT
Debt Instrument, Term		5 years
Long-term Debt							$ 556,049,000				$ 556,049,000			$ 471,129,000
Other Long-term Debt, Current							(4,500,000)				(4,500,000)			(4,500,000)
Other Long-term Debt							443,549,000				443,549,000			445,629,000
Long-term Debt, Gross							$ 560,549,000				560,549,000
number of amendments							4
Noncash or Part Noncash Acquisition, Investments Acquired											13,000,000
Line of Credit Facility, Amount Outstanding							$ 200,000,000				200,000,000
Average outstanding borrowings							276,441,000			$ 189,993,000	$ 265,537,000	$ 191,567,000
Line of Credit Facility, Interest Rate Description	0.01
Maximum quarterly distributions until the target leverage ratio is achieved (in dollars per share) | $ / shares											$ 0.40
Maximum borrowings							563,625,000			$ 226,850,000	$ 563,625,000	267,300,000
Proceeds from Issuance of Other Long-term Debt	$ 450,000,000										102,000,000	$ 134,000,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net							0				0
Amortization of Debt Discount (Premium)	0.01
Debt Instrument, Periodic Payment	$ 1,125,000
General Partner [Member]
LONG TERM DEBT
Line of Credit Facility, Amount Outstanding							22,480,000				22,480,000			30,130,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net							579,000				579,000
Credit Facility, due November 2017
LONG TERM DEBT
Long-term Debt							$ 117,000,000				117,000,000			30,000,000
unused borrowings															$ 350,000,000	$ 250,000,000	$ 350,000,000
Debt Instrument Leverage Ratio	4.50							5.75	5.75
Debt Instrument, Covenant Maximum Adjusted Consolidated Total Leverage Ratio							5.50
Line of Credit Facility, Remaining Borrowing Capacity							$ 60,520,000				$ 60,520,000			$ 139,870,000
Applicable margin under LIBOR borrowings	4.25%
Weighted average interest rate							5.15%			2.70%	5.13%	3.60%
Letters of credit
LONG TERM DEBT
unused borrowings	$ 75,000,000																$ 75,000,000
Credit Agreement, due June 2014
LONG TERM DEBT
Applicable margin under LIBOR borrowings													3.25%
Secured Debt [Member]
LONG TERM DEBT
Debt Instrument, Covenant Maximum Adjusted Consolidated Total Leverage Ratio							5.25
Pipelines [Member]
LONG TERM DEBT
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net	$ 100,000,000
Credit Facility [Domain]
LONG TERM DEBT
Debt Instrument, Term											5 years
Term Loan [Member]
LONG TERM DEBT
Debt Instrument, Term							7 years
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%
Base Rate [Member]
LONG TERM DEBT
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]
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%
Subsequent Event [Member] | Credit Facility, due November 2017
LONG TERM DEBT
Debt Instrument Leverage Ratio			5	5.25	5.5
Subsequent Event [Member] | Secured Debt [Member]
LONG TERM DEBT
Debt Instrument, Covenant Maximum Adjusted Consolidated Total Leverage Ratio						5

COMMITMENTS AND CONTINGENCIES46

COMMITMENTS AND CONTINGENCIES (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Purchase commitments
Capital Lease Obligations, Current	$ 435,000		$ 435,000		$ 455
Capital leases
Amortization expense related to the capital leases	100,000	$ 100,000	300,000	$ 300,000
Capital Lease Obligations Incurred	200,000	100,000	389,000	500,000
Operating Leases
Expenses associated with operating leases	600,000	$ 400,000	1,700,000	$ 700,000
Deferred Rent Credit	1,100,000		1,100,000
Capital Lease Obligations, Noncurrent	664,000		664,000		578
Capital Lease Obligations	$ 1,099,000		1,099,000		$ 1,033
Equipment related to capital projects
Purchase commitments
Commitments			25,700,000
Other Capital Projects [Member]
Purchase commitments
Commitments			$ 0

TRANSACTIONS WITH RELATED PAR47

TRANSACTIONS WITH RELATED PARTIES (Details)	Mar. 08, 2014	Mar. 06, 2014	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)director	Jun. 30, 2014USD ($)	Dec. 31, 2014USD ($)	Mar. 31, 2014$ / shares	May. 15, 2013$ / shares
Related Party Transactions
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party			$ 3,845,000	$ 3,576,000	$ 7,080,000	$ 7,051,000
Management fees incurred			76,000	110,000	$ 146,000	215,000
Number of directors | director					3
Affiliate Costs					$ 17,858,000	0
Related Party Transaction Reimbursement Expenses from Transactions with Related Party			5,133,000	4,113,000	10,432,000	8,056,000
Related Party Transaction, Amounts of Transaction			8,978,000	7,689,000	17,512,000	15,107,000
Compensation			200,000		400,000	300,000
Revenue from Related Parties			21,091,000	0	28,538,000	0
Accounts Receivable, Related Parties			19,779,000		19,779,000		$ 11,325,000
Due to Affiliate, Current			14,294,000		14,294,000		$ 12,856,000
Contractual Agreement, Term	10 years	10 years
Due to Affiliate			14,300,000		14,300,000
Preferred units issued
Related Party Transactions
Purchase price of units (in dollars per share) | $ / shares								$ 22.86	$ 22.86
Management fees incurred
Related Party Transactions
Management fees incurred			42,000	110,000	80,000	215,000
Management fees incurred | Vested units
Related Party Transactions
Management fees incurred			0		0
EIG [Member]
Related Party Transactions
Management fees incurred			17,000	0	33,000	0
Affiliates of Wells Fargo Bank NA [Member]
Related Party Transactions
Payments for Fees			400,000	200,000	700,000
Tailwater [Member]
Related Party Transactions
Management fees incurred			17,000	$ 0	33,000	$ 0
T2 LaSalle [Member]
Related Party Transactions
Due from Affiliate, Current			100,000		100,000
Due to Affiliate			0		0
T2 Eagle Ford [Member]
Related Party Transactions
Due from Affiliate, Current			1,400,000		1,400,000
Due to Affiliate			500,000		500,000
TexStar Rich Gas System [Member]
Related Party Transactions
Due from Affiliate, Current			16,900,000		16,900,000
Due to Affiliate			13,000,000		13,000,000
T2 Cogen [Member]
Related Party Transactions
Due from Affiliate, Current			0		0
Due to Affiliate			400,000		400,000
Southcross Holdings Common [Member]
Related Party Transactions
Due from Affiliate, Current			1,400,000		1,400,000
General Partner [Member]
Related Party Transactions
Due to Affiliate			300,000		300,000
valley wells [Member]
Related Party Transactions
Affiliate Costs					518,000
Revenue from Related Parties			$ 1,660,000		7,049,000
Limited Partner, units authorized | valley wells [Member]
Related Party Transactions
Affiliate Costs					$ 518,000

SERIES A PREFERRED UNITS (Detai

SERIES A PREFERRED UNITS (Details) - Class of Stock [Domain] - USD ($)	Aug. 04, 2014	May. 15, 2013	Apr. 12, 2013	Jun. 30, 2015	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2015	Jun. 30, 2014
Capital contribution						$ 3,115,000	$ (1,281,000)	$ (3,115,000)
Ownership interest held by general partners (as a percent)							2.00%
Valuation adjustment to maximum redemption value				$ (61,000)
Accrued distribution equivalent rights on the LTIP units					$ (5,062,000)	6,301,000		$ (5,029,000)
General Partner [Member]
Capital contribution						3,115,000	$ (1,281,000)
Ownership interest held by general partners (as a percent)	2.00%						2.00%
Accrued distribution equivalent rights on the LTIP units						$ 25,000
Preferred units issued
Conversion of Stock, Shares Converted				2,015,638
Preferred units issued		248,675	1,466,325		1,500,000
Purchase price of units (in dollars per share)		$ 22.86				$ 22.86
Accrued distribution equivalent rights on the LTIP units				$ 0			$ 0
Exchange ratio of conversion of preferred units into common units on satisfaction of specified condition				1
Preferred units issued | General Partner [Member]
Capital contribution							$ 800,000
Ownership interest held by general partners (as a percent)							2.00%
Preferred units issued | Vested units
Preferred units issued					1,715,000

PARTNERS' CAPITAL (Details)

PARTNERS' CAPITAL (Details) - USD ($)	Nov. 13, 2014	Aug. 04, 2014	Apr. 12, 2013	Feb. 28, 2014	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Mar. 05, 2015	Nov. 05, 2014
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross											10,730
Partners' Capital Account, Public Sale of Units										$ 144,671,000
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit					$ 0.40
Partners' Capital Account, Distributions											$ 23,306,000
Ownership Interest Percentage of Parent in Consolidated Subsidiaries					57.40%						57.40%
Capital contribution										3,115,000	$ (1,281,000)	$ (3,115,000)
Ownership interest held by general partners (as a percent)											2.00%
Preferred Stock, Participation Rights					1
Maximum quarterly distributions until the target leverage ratio is achieved (in dollars per share)											$ 0.40
Partners' Capital Account, Public Sale of Units Net of Offering Costs	$ 75,000,000
Limited Partner, units authorized
Distribution Made to Limited Partner, Unit Distribution											0
Common Unit, Issued					0						0
Partners' Capital Account, Public Sale of Units													$ 144,700,000
Partners' Capital Account, Distributions											$ 19,040,000
Limited Partner, units authorized					25,179,351		13,963,713				25,179,351		13,963,713
Capital contribution											$ 0
Limited Partner, units outstanding					21,454,119		12,253,985				21,454,119		12,253,985
Common Stock, Shares, Outstanding					21,695,273		21,684,543				21,695,273		21,684,543
Southcross Holdings Common [Member]
Distribution Made to Limited Partner, Unit Distribution											0
Common Unit, Issued					4,500,000						4,500,000
Ownership interest held by general partners (as a percent)		100.00%
Common Stock, Shares, Outstanding					6,616,400		2,116,400				6,616,400		2,116,400
Class B Convertible Units [Member]
Distribution Made to Limited Partner, Unit Distribution											525,676
Common Unit, Issued					0						0
Partners' Capital Account, Distributions											$ 0
Capital contribution											$ 0
Preferred Units, Outstanding					15,414,754		14,889,078				15,414,754		14,889,078
Subordinated Units [Member]
Distribution Made to Limited Partner, Unit Distribution											0
Common Unit, Issued					0						0
Shares, Outstanding														12,213,713
Preferred Units, Outstanding					12,213,713		12,213,713				12,213,713		12,213,713
Subordinated Units [Member]
Partners' Capital Account, Public Sale of Units										0
Limited Partner, units issued							12,213,713						12,213,713
Partners' Capital Account, Distributions											$ 3,432,000
Limited Partner, units authorized		12,213,713			12,213,713						12,213,713
Capital contribution										0
Limited Partner, units outstanding					12,213,713		12,213,713				12,213,713		12,213,713
General Partner [Member]
Distribution Made to Limited Partner, Unit Distribution											102,783
Common Unit, Issued					0						0
Partners' Capital Account, Public Sale of Units										0
Partners' Capital Account, Distributions											$ 834,000
Capital contribution										3,115,000	$ (1,281,000)
Ownership interest held by general partners (as a percent)		2.00%									2.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest				2.00%
Partners' Capital Account, Units					1,141,635		1,038,852				1,141,635		1,038,852
Common Units [Member]
Common Stock, Shares, Issued					4,500,000						4,500,000
Common Units [Member]
Common Stock, Shares, Outstanding															2,116,400
Class B Convertible Units [Member]
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit					$ 0.3257
Partners' Capital Account, Distributions											$ 0.44
Class B Convertible Units [Member] | Class B Convertible Units [Member]
Conversion of Stock, Shares Issued		14,633,000
Common Stock [Member]
Partners' Capital Account, Units, Authorized for Public Offering				9,200,000
Limited Partners' Offering Costs							$ 400,000						$ 400,000
TexStar Rich Gas System [Member]
Business Acquisition, Percentage of Voting Interests Acquired		100.00%
Ownership interest held by general partners (as a percent)		33.00%
Cash Distribution [Member]
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit					$ 0.4		$ 0.4		$ 0.4
Distribution Made to Member or Limited Partner, Distribution Paid in Cash					$ 11,782,000	$ 9,938,000	$ 13,368,000	$ 9,933,000	$ 14,575,000	$ 13,762,000
Cash Distribution [Member] | General Partner [Member]
Distribution Made to Member or Limited Partner, Distribution Paid in Cash					$ 457,000	$ 418,000	416,000	$ 413,000	$ 290,000
Cash Distribution [Member] | Subordinated Units [Member]
Distribution Made to Member or Limited Partner, Distribution Paid in Cash							$ 0.28
Series A Convertible Preferred Units [Member]
Conversion of Stock, Shares Converted					2,015,638
Preferred unit Conversion Common Units Exchange Ratio on Satisfaction of Specified Condition			110.00%
Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit											$ 0.40
Series A Convertible Preferred Units [Member] | General Partner [Member]
Capital contribution											$ 800,000
Ownership interest held by general partners (as a percent)											2.00%

INCENTIVE COMPENSATION (Details

INCENTIVE COMPENSATION (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Mar. 31, 2014	Mar. 31, 2013
Unit based compensation
Allocated Share-based Compensation Expense	$ 1,662,000	$ 1,082,000	$ 2,475,000	$ 1,611,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	38,997
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	390,378
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	84,423
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Intrinsic Value, Amount Per Share	$ 13.84
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Period Increase (Decrease)	(145,688)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	$ 19.53
Shares Paid for Tax Withholding for Share Based Compensation			(10,667)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other Than Options, Recaptured for Tax Withholding, Weighted Average Grant Date Fair Value			$ 21.69
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Number	(44,425)		(44,425)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Exercise Price	$ 19.03		$ 19.03
Weighted-average grant date fair value
Unit-based compensation			$ 500,000
Long Term Incentive Plan [Member]
Unit based compensation
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	660,348		660,348		470,750
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 17.84		$ 17.84		$ 20.45
Incentive Plan
Unit based compensation
Vesting period			3 years
Weighted-average grant date fair value
Fair value		5,400,000	$ 5,400,000
Share-based compensation cost not yet recognized	$ 9,100,000		$ 9,100,000				$ 7,500,000
Units available for issuance (in shares)	666,261		666,261			1,213,642
Matching contributions expensed for employee savings plan
Unit based compensation
Matching contributions expensed for employee savings plan	$ 172,000	234,000	$ 340,000	590,000
Employer matching contribution, percent of employee's contribution			100.00%
Weighted-average grant date fair value
Employer matching contribution, percent of employees' gross pay			6.00%
Maximum annual contributions by employer, amount (per employee)			$ 17,500
1yr vesting period [Domain] | Incentive Plan
Weighted-average grant date fair value
Period of amortization of compensation expense			1 year
3yr vesting period [Domain] | Incentive Plan
Weighted-average grant date fair value
Period of amortization of compensation expense			3 years
Designated as Hedging Instrument [Member] | Interest Rate Cap [Member]
Unit based compensation
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net		0		(11,000)
Weighted-average grant date fair value
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		$ 106,000		$ 221,000

REVENUES (Details)

REVENUES (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues [Abstract]
Sales of natural gas	$ 92,518	$ 123,401	$ 205,304	$ 268,759
Sales of NGLs and condensate	39,427	54,282	76,610	106,155
Transportation, gathering and processing fees	33,823	17,279	68,876	33,394
Other	1,452	101	2,368	346
Total revenues	$ 167,220	$ 195,063	$ 353,158	$ 408,654

CONCENTRATION OF CREDIT RISK 52

CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE (Details) - Customer concentration - Consolidated revenue - customer	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Sherwin Alumina Company [Member]
Consolidated revenue concentration
Concentration risk percentage		12.20%		11.00%
Dow Hydrocarbons & Resources LLC
Consolidated revenue concentration
Concentration risk percentage	13.00%	13.00%	11.80%	12.60%
Top ten customers
Consolidated revenue concentration
Number of top customers			10	10
Concentration risk percentage	55.80%	73.00%	56.80%	68.60%

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details)

May. 07, 2015USD ($)

Apr. 23, 2015$ / shares

Aug. 04, 2014USD ($)

Apr. 12, 2013

Feb. 28, 2014

Dec. 31, 2016

Sep. 30, 2016

Dec. 31, 2015

Sep. 30, 2015

Jun. 30, 2015USD ($)$ / shares

Mar. 31, 2015$ / shares

Dec. 31, 2014$ / shares

Sep. 30, 2014$ / shares

Jun. 30, 2014$ / shares

Jun. 30, 2015USD ($)director$ / shares

Jun. 30, 2014USD ($)

Aug. 07, 2015shares

Mar. 13, 2014USD ($)

Mar. 27, 2013USD ($)

Nov. 07, 2012USD ($)

Subsequent events

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net | $

$ 0

$ 0

Entity Common Stock, Shares Outstanding | shares

28,311,673

Ownership interest held by general partners (as a percent)

2.00%

Number of directors | director

3

Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit

$ 0.40

Payments to Acquire Businesses, Gross | $

$ 77,600,000

$ 80,000,000

Payments to Acquire Businesses, Net of Cash Acquired | $

$ 15,000,000

0

$ 38,636,000

General Partner interest [Member]

Subsequent events

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net | $

$ 579,000

$ 579,000

Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest

2.00%

Ownership interest held by general partners (as a percent)

2.00%

2.00%

Cash

Subsequent events

Distribution Made to Member or Limited Partner Unit Distributions Per Unit

$ 0.3257

$ 0.3257

$ 0.3257

$ 0.3257

Distribution per common and subordinated unit (in dollars per unit)

$ 0.40

Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit

0.4

$ 0.4

$ 0.4

Series A convertible preferred units

Subsequent events

Preferred unit Conversion Common Units Exchange Ratio on Satisfaction of Specified Condition

110.00%

Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit

$ 0.40

Series A convertible preferred units | General Partner interest [Member]

Subsequent events

Ownership interest held by general partners (as a percent)

2.00%

Maximum [Member] | Cash

Subsequent events

Distribution Made to Member or Limited Partner Distribution Period

45 days

Class B Convertible Units [Member]

Subsequent events

Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit

0.3257

Subordinated Limited Partners [Member] | Cash | Limited Partner [Member]

Subsequent events

Distribution Made to Member or Limited Partner Minimum Quarterly Distributions Declared Per Unit

$ 0.40

$ 0.40

Senior Secured Credit Facility [Member]

Subsequent events

Line of Credit Facility, Maximum Borrowing Capacity | $

$ 350,000,000

$ 250,000,000

$ 350,000,000

Debt Instrument Leverage Ratio

4.50

5.75

5.75

Debt Instrument, Covenant Maximum Adjusted Consolidated Total Leverage Ratio

5.50

Senior Secured Credit Facility [Member] | Subsequent Event [Member]

Subsequent events

Debt Instrument Leverage Ratio

5

5.25

5.5

Letter of Credit [Member]

Subsequent events

Line of Credit Facility, Maximum Borrowing Capacity | $

$ 75,000,000

$ 75,000,000

Secured Debt [Member]

Subsequent events

Debt Instrument, Covenant Maximum Adjusted Consolidated Total Leverage Ratio

5.25

Secured Debt [Member] | Subsequent Event [Member]

Subsequent events

Debt Instrument, Covenant Maximum Adjusted Consolidated Total Leverage Ratio

5

Pipelines [Member]

Subsequent events

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net | $

$ 100,000,000

SUPPLEMENTAL INFORMATION (Detai

SUPPLEMENTAL INFORMATION (Details) - Class of Stock [Domain] $ in Thousands	May. 08, 2015USD ($)	Aug. 04, 2014USD ($)	Mar. 08, 2014	Mar. 06, 2014plant	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Sep. 30, 2014USD ($)	Jun. 30, 2014USD ($)	Mar. 31, 2014USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Dec. 31, 2013USD ($)
Operating Leased Assets [Line Items]
Interest Paid, Net											$ 14,221	$ 4,200
Proceeds from Income Tax Refunds											58	185
Supplemental disclosures of non-cash investing and financing activities:												9,656
Accounts payable related to capital expenditures											0	11
Repayments of Debt and Capital Lease Obligations											342	466
Noncash Financing Activities, Accrued Distribution on Long Term Incentive Plan											444	259
Interest Costs Incurred [Abstract]
Total interest costs					$ 8,531				$ 2,225		16,406	5,297
Capitalized interest included in property, plant and equipment, net					(631)				(454)		(1,008)	(553)
Interest expense					7,900				1,771		15,398	4,744
Deferred Financing Costs [Roll Forward]
Deferred financing costs, January 1					15,642		$ 16,602			$ 4,728	15,642		$ 5,237
Capitalization of deferred financing costs									166		597
Amortization of Financing Costs and Discounts											1,557
Amortization of deferred financing costs									(675)		(1,727)	(675)
Deferred financing costs, June 30					$ 15,642		16,602			4,728	$ 15,642
Number of power plants				2	2						2
Contractual agreement, term			10 years	10 years
Contingent fees					$ (700)				(700)		$ (1,300)	(900)
Business Combination, Contingent Consideration Arrangements, Change in Amount of Contingent Consideration, Liability					(800)				(300)		(1,500)	(400)
Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure												0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net					0						0
Temporary Equity Accretion Preferred Unit In-kind Distribution									(5,062)	6,301		(5,029)
Affiliate Costs											17,858	0
Business Combination, Consideration Transferred	$ 28,980	$ 98,625									15,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities		100,000
Cash advance from Holdings to contributed subsidiaries, net												$ 1,688
Natural Gas Pipeline Contracts [Member]
Deferred Financing Costs [Roll Forward]
Operating Leases, Future Minimum Payments, Due in Two Years					2,800						2,800
Operating leases, future minimum payments due in third year					5,600						5,600
Operating Leases, Future Minimum Payments, Due in Four Years					5,600						5,600
Operating leases, future minimum payments due in fifth year					2,200						2,200
Operating leases, future minimum payments due in sixth year					2,200						2,200
Operating leases, future minimum payments due after sixth year					15,300						15,300
valley wells [Member]
Deferred Financing Costs [Roll Forward]
Affiliate Costs											518
Business Combination, Consideration Transferred	$ 14,442
TexStar Rich Gas System [Member]
Deferred Financing Costs [Roll Forward]
Goodwill		98,625
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net		(305,789)
In Kind Distribution [Member] | Class B Convertible Units [Member]
Operating Leased Assets [Line Items]
Supplemental disclosures of non-cash investing and financing activities:											9,615
Deferred Financing Costs [Roll Forward]
Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure					2,994	$ 3,712	$ 4,143	$ 5,467	$ 0		6,706
Southcross Holdings Common [Member]
Deferred Financing Costs [Roll Forward]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net					28,980						28,980
Temporary Equity Accretion Preferred Unit In-kind Distribution										$ 0
Business Combination, Consideration Transferred											77,640
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities					700						700
Southcross Holdings Common [Member] | valley wells [Member]
Deferred Financing Costs [Roll Forward]
Affiliate Costs											0
Limited Partner, units authorized
Deferred Financing Costs [Roll Forward]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net					(14,442)						(14,442)
Business Combination, Consideration Transferred		$ 45,420									62,640
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities					$ 0						0
Limited Partner, units authorized | valley wells [Member]
Deferred Financing Costs [Roll Forward]
Affiliate Costs											$ 518

EQUITY IN JOINT VENTURES (Detai

EQUITY IN JOINT VENTURES (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015USD ($)joint_venture	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)joint_venture	Jun. 30, 2014USD ($)	Aug. 04, 2014
number of joint ventures | joint_venture	3		3
Equity Method Investment Summarized Financial Information, Equity	$ 142,197		$ 142,197
Income (Loss) from Equity Method Investments	(3,604)		(7,155)
Natural Gas Midstream Revenue	167,220	$ 195,063	353,158	$ 408,654
Net Income (Loss) Attributable to Parent	(15,451)	(2,961)	(29,356)	(4,249)
Revenues	146,129	$ 195,063	324,620	$ 408,654
T2 Eagle Ford [Member]
Equity Method Investment Summarized Financial Information, Equity	104,817		104,817
Income (Loss) from Equity Method Investments	(2,496)		(4,988)
Natural Gas Midstream Revenue	1,215		2,136
Net Income (Loss) Attributable to Parent	(4,993)		(9,975)
T2 Cogen [Member]
Equity Method Investment Summarized Financial Information, Equity	18,740		18,740
Income (Loss) from Equity Method Investments	(746)		(1,426)
Natural Gas Midstream Revenue	1,187		2,849
Net Income (Loss) Attributable to Parent	(1,492)		(2,853)
T2 LaSalle [Member]
Equity Method Investment Summarized Financial Information, Equity	18,640		18,640
Income (Loss) from Equity Method Investments	(362)		(741)
Natural Gas Midstream Revenue	450		829
Net Income (Loss) Attributable to Parent	$ (1,445)		$ (2,965)
T2 LaSalle [Member]
Equity Method Investment, Ownership Percentage					25.00%
T2 Cogen [Member]
Equity Method Investment, Ownership Percentage					50.00%
T2 Eagle Ford [Member]
Equity Method Investment, Ownership Percentage	50.00%		50.00%

Uncategorized Items - sxe-20150

Label	Element	Value
Limited Partners' Capital Account, Distribution Amount	us-gaap_LimitedPartnersCapitalAccountDistributionAmount	$ 27,516
Partners' Capital Account, Income Tax Withholdings on Vested Units	sxe_PartnersCapitalAccountIncomeTaxWithholdingsonVestedUnits	(37)
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	us-gaap_OtherComprehensiveIncomeLossDerivativesQualifyingAsHedgesNetOfTax	210
Partners' Capital Account, Unit-based Compensation	us-gaap_PartnersCapitalAccountUnitBasedCompensation	1,513
Accrued Distribution on Long Term Incentive Plan	sxe_AccruedDistributionOnLongTermIncentivePlan	(259)
General Partner Distributions	us-gaap_GeneralPartnerDistributions	0
General Partner [Member]
Limited Partners' Capital Account, Distribution Amount	us-gaap_LimitedPartnersCapitalAccountDistributionAmount	579
Partners' Capital Account, Income Tax Withholdings on Vested Units	sxe_PartnersCapitalAccountIncomeTaxWithholdingsonVestedUnits	0
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	us-gaap_OtherComprehensiveIncomeLossDerivativesQualifyingAsHedgesNetOfTax	0
Partners' Capital Account, Unit-based Compensation	us-gaap_PartnersCapitalAccountUnitBasedCompensation	0
Accrued Distribution on Long Term Incentive Plan	sxe_AccruedDistributionOnLongTermIncentivePlan	0
General Partner Distributions	us-gaap_GeneralPartnerDistributions	26
Subordinated Limited Partners [Member]
Limited Partners' Capital Account, Distribution Amount	us-gaap_LimitedPartnersCapitalAccountDistributionAmount	9,771
Temporary Equity Accretion Preferred Unit In-kind Distribution	sxe_TemporaryEquityAccretionPreferredUnitInkindDistribution	(474)
Partners' Capital Account, Income Tax Withholdings on Vested Units	sxe_PartnersCapitalAccountIncomeTaxWithholdingsonVestedUnits	0
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	us-gaap_OtherComprehensiveIncomeLossDerivativesQualifyingAsHedgesNetOfTax	0
Partners' Capital Account, Unit-based Compensation	us-gaap_PartnersCapitalAccountUnitBasedCompensation	0
Accrued Distribution on Long Term Incentive Plan	sxe_AccruedDistributionOnLongTermIncentivePlan	0
General Partner Distributions	us-gaap_GeneralPartnerDistributions	10
Southcross Holdings Common [Member]
Partners' Capital Account, Contributions	us-gaap_PartnersCapitalAccountContributions	0
Limited Partners' Capital Account, Distribution Amount	us-gaap_LimitedPartnersCapitalAccountDistributionAmount	0
Partners' Capital Account, Income Tax Withholdings on Vested Units	sxe_PartnersCapitalAccountIncomeTaxWithholdingsonVestedUnits	0
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	us-gaap_OtherComprehensiveIncomeLossDerivativesQualifyingAsHedgesNetOfTax	210
Partners' Capital Account, Unit-based Compensation	us-gaap_PartnersCapitalAccountUnitBasedCompensation	0
Partners' Capital Account, Public Sale of Units	us-gaap_PartnersCapitalAccountPublicSaleOfUnits	0
Accrued Distribution on Long Term Incentive Plan	sxe_AccruedDistributionOnLongTermIncentivePlan	0
General Partner Distributions	us-gaap_GeneralPartnerDistributions	0
Common Units [Member] | Common Limited Partners [Member]
Partners' Capital Account, Contributions	us-gaap_PartnersCapitalAccountContributions	0
Limited Partners' Capital Account, Distribution Amount	us-gaap_LimitedPartnersCapitalAccountDistributionAmount	17,166
Temporary Equity Accretion Preferred Unit In-kind Distribution	sxe_TemporaryEquityAccretionPreferredUnitInkindDistribution	(5,802)
Partners' Capital Account, Income Tax Withholdings on Vested Units	sxe_PartnersCapitalAccountIncomeTaxWithholdingsonVestedUnits	(37)
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	us-gaap_OtherComprehensiveIncomeLossDerivativesQualifyingAsHedgesNetOfTax	0
Partners' Capital Account, Unit-based Compensation	us-gaap_PartnersCapitalAccountUnitBasedCompensation	1,513
Partners' Capital Account, Public Sale of Units	us-gaap_PartnersCapitalAccountPublicSaleOfUnits	144,671
Accrued Distribution on Long Term Incentive Plan	sxe_AccruedDistributionOnLongTermIncentivePlan	(259)
General Partner Distributions	us-gaap_GeneralPartnerDistributions	$ 16