Southcross Energy Partners 10-K 5 Mar 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Jun. 30, 2013	Feb. 28, 2014	Feb. 28, 2014	Feb. 28, 2014
			Common Units	Subordinated Units	Series A Convertible Preferred Units [Member]
Entity Registrant Name	'Southcross Energy Partners, L.P.	'	'	'	'
Entity Central Index Key	'0001547638	'	'	'	'
Document Type	'10-K	'	'	'	'
Document Period End Date	31-Dec-13	'	'	'	'
Amendment Flag	'false	'	'	'	'
Current Fiscal Year End Date	'--12-31	'	'	'	'
Entity Well-known Seasoned Issuer	'No	'	'	'	'
Entity Voluntary Filers	'No	'	'	'	'
Entity Current Reporting Status	'Yes	'	'	'	'
Entity Filer Category	'Accelerated Filer	'	'	'	'
Entity Public Float	'	$229,045,500	'	'	'
Entity Common Stock, Shares Outstanding	'	'	21,454,119	12,213,713	1,800,886
Document Fiscal Year Focus	'2013	'	'	'	'
Document Fiscal Period Focus	'FY	'	'	'	'

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$3,349	$7,490
Trade accounts receivable	57,669	50,994
Prepaid expenses	3,061	1,762
Other current assets	5,105	1,001
Total current assets	69,184	61,247
Property, plant and equipment, net	575,795	550,603
Intangible assets, net	1,568	1,624
Other assets	5,768	5,131
Total assets	652,315	618,605
Current liabilities:	'	'
Accounts payable and accrued liabilities	62,451	96,801
Other current liabilities	5,344	3,586
Total current liabilities	67,795	100,387
Long-term debt	267,300	191,000
Other non-current liabilities	1,692	751
Total liabilities	336,787	292,138
Commitments and contingencies	'	'
Partners' capital:	'	'
Accumulated other comprehensive loss	-210	-477
Partners' capital:	'	'
Total partners' capital	275,024	326,467
Liabilities, preferred units, partners' capital and members' equity:	'	'
Total liabilities, preferred units and partners' capital	652,315	618,605
Common Units	'	'
Partners' capital:	'	'
Partners' capital units	169,141	194,364
Partners' capital:	'	'
Total partners' capital	169,141	194,364
Subordinated Units	'	'
Partners' capital:	'	'
Partners' capital units	99,726	125,952
Partners' capital:	'	'
Total partners' capital	99,726	125,952
General Partner Units [Member]	'	'
Partners' capital:	'	'
General Partner interest	6,367	6,628
Partners' capital:	'	'
Total partners' capital	6,367	6,628
Redeemable	'	'
Preferred units of Southcross Energy LLC:	'	'
Series A convertible preferred units (1,769,915 units issued and outstanding as of December 31, 2013)	$40,504	$0

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical)	Dec. 31, 2013	Dec. 31, 2012
Common Units	'	'
Partners' capital:	'	'
Limited Partner, units issued	12,253,985	12,213,713
Limited Partner, units outstanding	12,253,985	12,213,713
Limited Partners' Capital Account, Units Authorized	13,963,713	13,963,713
Subordinated Units	'	'
Partners' capital:	'	'
Limited Partner, units issued	12,213,713	12,213,713
Limited Partner, units outstanding	12,213,713	12,213,713
Limited Partners' Capital Account, Units Authorized	12,213,713	12,213,713
Redeemable	'	'
Partners' capital:	'	'
Series A convertible preferred units issued	1,769,915	'
Series A convertible preferred units outstanding	1,769,915	'

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	2 Months Ended	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Revenues	$96,047	$634,722	$496,129	$523,149
Expenses:	'	'	'	'
Cost of natural gas and liquids sold	'	541,176	424,489	460,580
Operations and maintenance	'	41,254	35,532	25,229
Depreciation and amortization	'	33,548	18,977	12,345
General and administrative	'	21,764	13,842	9,129
Total expenses	'	637,742	492,840	507,283
(Loss) income from operations	-3,998	-3,020	3,289	15,866
Loss on extinguishment of debt	'	0	-1,764	-3,240
Gain on sale of assets, net	'	25	0	522
Interest expense	'	-12,590	-5,767	-5,348
(Loss) income before income tax expense	'	-15,585	-4,242	7,800
Income tax expense	'	-385	-246	-261
Net (loss) income	-4,228	-15,970	-4,488	7,539
Series A convertible preferred unit in-kind distribution and fair value adjustment	'	-1,670	'	'
Net loss attributable to partners	-4,228	-17,640	'	'
Less deemed dividend on:	'	'	'	'
Net loss attributable to Southcross Energy LLC common unitholders	'	'	-22,910	-8,145
Basic and diluted earnings per unit	'	'	'	'
Weighted average number of Southcross Energy LLC common units outstanding	'	'	1,198,429	1,197,876
Basic and diluted net loss per Southcross Energy LLC common unit	($0.17)	($0.71)	($19.12)	($6.79)
General Partner [Member]	'	'	'	'
Expenses:	'	'	'	'
Net (loss) income	-85	-319	-85	'
Series A convertible preferred unit in-kind distribution and fair value adjustment	'	-1,670	'	'
Basic and diluted earnings per unit	'	'	'	'
Basic and diluted net loss per Southcross Energy LLC common unit	($0.17)	'	($0.17)	'
Limited Partners [Member]	'	'	'	'
Expenses:	'	'	'	'
Net (loss) income	-4,143	-17,321	-4,143	'
Basic and diluted earnings per unit	'	'	'	'
Basic and diluted net loss per Southcross Energy LLC common unit	($0.17)	'	($0.17)	'
Common Units	'	'	'	'
Expenses:	'	'	'	'
Net (loss) income	-2,072	-7,829	'	'
Less deemed dividend on:	'	'	'	'
Net loss attributable to Southcross Energy LLC common unitholders	-2,072	-8,683	'	'
Net income (loss) allocated to limited partners	-2,072	-8,683	'	'
Basic and diluted earnings per unit	'	'	'	'
Weighted average number of partner units outstanding (in shares)	12,213,713	12,224,997	'	'
Loss per unit (in dollars per share)	($0.17)	($0.71)	'	'
Subordinated Units	'	'	'	'
Expenses:	'	'	'	'
Net (loss) income	-2,071	-7,822	'	'
Less deemed dividend on:	'	'	'	'
Net income (loss) allocated to limited partners	-2,071	-8,638	'	'
Basic and diluted earnings per unit	'	'	'	'
Weighted average number of partner units outstanding (in shares)	12,213,713	12,213,713	'	'
Loss per unit (in dollars per share)	($0.17)	($0.71)	'	'
Redeemable	'	'	'	'
Less deemed dividend on:	'	'	'	'
Preferred units	'	'	-2,693	-1,553
Series B	'	'	'	'
Less deemed dividend on:	'	'	'	'
Preferred units	'	'	-4,696	'
Series C	'	'	'	'
Less deemed dividend on:	'	'	'	'
Preferred units	'	'	-2,012	'
Preferred	'	'	'	'
Less deemed dividend on:	'	'	'	'
Preferred units	'	'	($13,249)	($14,131)

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Statement of Comprehensive Income [Abstract]	'	'	'
Net (loss) income	($15,970)	($4,488)	$7,539
Other comprehensive income (loss):	'	'	'
Hedging losses reclassified to earnings and recognized in interest expense	415	268	'
Adjustment in fair value of derivatives	-148	-745	'
Total other comprehensive income (loss)	267	-477	'
Comprehensive (loss) income	($15,703)	($4,965)	$7,539

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Redeemable

Redeemable

Redeemable

Series B

Series B

Series B

Series C

Series C

Series C

Common Units

Common Units

Common Units

Common units [Member]

Common units [Member]

Common units [Member]

Cash flows from operating activities:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net (loss) income

($15,970)

($4,488)

$7,539

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Adjustments to reconcile net (loss) income to net cash provided by operating activities:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Depreciation and amortization

33,548

18,977

12,345

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unit-based compensation

2,186

630

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss on extinguishment of debt

0

1,764

3,240

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization of deferred financing costs

1,287

1,183

882

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain on sale of assets, net

-25

'

-522

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrealized (gain) loss

-120

141

21

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other, net

130

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Changes in operating assets and liabilities:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Trade accounts receivable

-6,675

-9,760

-2,806

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Prepaid expenses and other current assets

-1,197

-1,246

-497

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other non-current assets

215

1,786

-2,155

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accounts payable and accrued liabilities

1,411

16,517

2,759

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other liabilities

1,183

-1,181

-799

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net cash provided by operating activities

15,973

24,323

20,007

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash flows from investing activities:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capital expenditures

-93,863

-169,816

-123,347

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of Enterprise Alabama Intrastate, LLC

'

'

-21,777

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expenditures related to repair of Gregory plant fire damage, net of insurance proceeds and deductible

-3,383

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from sale of property, plant and equipment

137

'

522

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net cash used in investing activities

-97,109

-169,816

-144,602

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash flows from financing activities:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of common units, net

'

187,764

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowings under our credit agreements

129,300

297,500

229,400

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayments under our credit agreements

-53,000

-314,780

-136,119

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments on capital lease obligations

-542

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Financing costs

-2,139

-5,178

-2,710

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayment of equity note

'

'

113

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of Series A convertible preferred units, net of issuance costs

38,832

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase and retirement of common units

'

'

'

'

'

'

'

'

'

'

'

'

'

-25,205

'

'

-15,300

'

Proceeds from issuance of preferred units

'

'

'

'

'

15,000

'

42,800

'

'

30,000

'

'

'

'

'

'

'

Distributions to Southcross Energy LLC

'

-46,030

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution to partners and LTIP unitholders

-35,992

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

LTIP tax withholdings on vested units

-264

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net cash provided by financing activities

76,995

151,571

105,684

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net (decrease) increase in cash and cash equivalents

-4,141

6,078

-18,911

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash and cash equivalents b Beginning of year

7,490

1,412

20,323

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash and cash equivalents b End of year

$3,349

$7,490

$1,412

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

CONSOLIDATED_STATEMENTS_OF_CHA

CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL AND MEMBERS' EQUITY (USD $)

Total

Redeemable preferred units

Series B redeemable preferred units

Series C redeemable preferred units

Preferred units

Series A preferred units

Common units [Member]

Common units [Member]

Accumulated Deficit

Accumulated Deficit

Accumulated Deficit

Accumulated Deficit

Accumulated Deficit

Accumulated Other Comprehensive Loss

General Partner [Member]

General Partner [Member]

Common Units

Common Units

Subordinated Units

Subordinated Units

Common Class A

Common Class B

Redeemable preferred units

Series B redeemable preferred units

Series C redeemable preferred units

Preferred units

Series A preferred units

Series A preferred units

Series A preferred units

BALANCE-Members' Equity at Dec. 31, 2010

($2,021,000)

'

'

'

'

'

$1,415,000

$57,000

($3,493,000)

'

'

'

'

$0

$0

'

$0

'

$0

'

Increase (Decrease) in Shareholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net (loss) income

7,539,000

'

'

'

'

'

'

'

7,539,000

'

'

'

'

'

'

'

'

'

'

'

Receipt of payment from unit note holder

1,000

'

'

'

'

'

1,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Deemed dividend on:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred units

'

-1,553,000

'

'

-14,131,000

'

'

'

'

-1,553,000

'

'

-14,131,000

'

'

'

'

'

'

'

Contribution by Southcross Energy LLC

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

BALANCE-Members' Equity at Dec. 31, 2011

-10,165,000

'

'

'

'

'

1,416,000

57,000

-11,638,000

'

'

'

'

0

0

'

0

'

0

'

Increase (Decrease) in Shareholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net (loss) income

-260,000

'

'

'

'

'

'

'

-260,000

'

'

'

'

'

'

'

'

'

'

'

Deemed dividend on:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred units

'

-2,693,000

-4,696,000

-2,012,000

-13,249,000

'

'

'

'

-2,693,000

-4,696,000

-2,012,000

-13,249,000

'

'

'

'

'

'

'

Repurchase and retirement of common units

-15,300,000

'

'

'

'

'

-131,000

'

-15,169,000

'

'

'

'

'

'

'

'

'

'

'

BALANCE-Partners' Capital at Nov. 06, 2012

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

BALANCE-Members' Equity at Dec. 31, 2011

-10,165,000

'

'

'

'

'

'

57,000

'

'

'

'

'

0

0

'

0

'

0

'

Increase (Decrease) in Shareholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net (loss) income

-4,488,000

'

'

'

'

'

'

'

'

'

'

'

'

'

-85,000

'

'

'

'

'

Deemed dividend on:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred units

'

-2,693,000

-4,696,000

-2,012,000

-13,249,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contribution by Southcross Energy LLC

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

BALANCE-Partners' Capital at Dec. 31, 2012

326,467,000

'

'

'

'

'

'

'

'

'

'

'

'

'

6,628,000

'

'

'

'

'

BALANCE-Partners' Capital at Nov. 07, 2012

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase (Decrease) in Shareholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net (loss) income

-4,228,000

'

'

'

'

'

'

'

'

'

'

'

'

'

-85,000

'

-2,072,000

'

-2,071,000

'

Deemed dividend on:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchase and retirement of common units

-25,205,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-25,205,000

'

'

'

Contribution by Southcross Energy LLC

262,826,000

'

'

'

'

'

-1,285,000

-57,000

49,717,000

'

'

'

'

'

6,713,000

'

43,274,000

'

164,464,000

'

Issuance of common units, net

187,764,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

187,764,000

'

'

'

Distributions to Southcross Energy LLC

-46,030,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-9,589,000

'

-36,441,000

'

Net loss attributable to period November 7, 2012 through December 31, 2012

192,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

192,000

'

'

'

Net effect of cash flow hedges

-477,000

'

'

'

'

'

'

'

'

'

'

'

'

-477,000

'

'

'

'

'

'

BALANCE-Partners' Capital at Dec. 31, 2012

326,467,000

'

'

'

'

'

0

0

0

'

'

'

'

-477,000

6,628,000

'

194,364,000

'

125,952,000

'

Increase (Decrease) in Shareholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net (loss) income

-6,382,000

'

'

'

'

'

'

'

'

'

'

'

'

'

-128,000

'

'

'

'

'

BALANCE-Partners' Capital at Mar. 31, 2013

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

BALANCE-Partners' Capital at Dec. 31, 2012

326,467,000

'

'

'

'

'

'

'

'

'

'

'

'

-477,000

6,628,000

'

194,364,000

'

125,952,000

'

Increase (Decrease) in Shareholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net (loss) income

-15,970,000

'

'

'

'

'

'

'

'

'

'

'

'

'

-319,000

'

-7,829,000

'

-7,822,000

'

Series A convertible preferred unit in-kind distribution and fair value adjustment

-1,670,000

'

'

'

'

'

'

'

'

'

'

'

'

'

-1,670,000

-33,000

'

-838,000

'

-799,000

Contributions from general partner

800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

800,000

'

0

'

0

'

Deemed dividend on:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contribution by Southcross Energy LLC

'

'

'

'

'

'

'

'

'

'

'

'

'

'

800,000

'

'

'

'

'

Net loss attributable to period November 7, 2012 through December 31, 2012

'

'

'

'

'

1,601,000

'

'

'

'

'

'

'

'

'

'

'

1,601,000

'

'

Distribution to partners

-35,928,000

'

'

'

'

'

'

'

'

'

'

'

'

'

-742,000

'

-17,597,000

'

-17,589,000

'

Accrued distribution on long-term incentive plan

-279,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-279,000

'

'

'

LTIP tax withholdings on vested units

-264,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-264,000

'

'

'

Distribution Made to Member or Limited Partner, Distribution Paid In-kind, Fair Value Disclosure

0

'

'

'

'

'

'

'

'

'

'

'

'

'

33,000

'

-17,000

'

-16,000

'

Net effect of cash flow hedges

267,000

'

'

'

'

'

'

'

'

'

'

'

'

267,000

'

'

'

'

'

'

BALANCE-Partners' Capital at Dec. 31, 2013

275,024,000

'

'

'

'

'

0

0

0

'

'

'

'

-210,000

6,367,000

'

169,141,000

'

99,726,000

'

BALANCE-Partners' Capital at Sep. 30, 2013

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase (Decrease) in Shareholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net (loss) income

673,000

'

'

'

'

'

'

'

'

'

'

'

'

'

14,000

'

'

'

'

'

BALANCE-Partners' Capital at Dec. 31, 2013

$275,024,000

'

'

'

'

'

$0

$0

$0

'

'

'

'

'

$6,367,000

'

'

'

'

'

ORGANIZATION_AND_DESCRIPTION_O

ORGANIZATION AND DESCRIPTION OF BUSINESS	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
ORGANIZATION AND DESCRIPTION OF BUSINESS	'
	ORGANIZATION, DESCRIPTION OF BUSINESS AND SIGNIFICANT ACCOUNTING POLICIES
	Organization
	Southcross Energy Partners, L.P. (the "Partnership," "Southcross," "we," "our" or "us") is a Delaware limited partnership formed in April 2012. Southcross Energy LLC is a Delaware limited liability company, and the predecessor for accounting purposes (the "Predecessor") of the Partnership. References in this Form 10-K to the Partnership, when used for periods prior to our initial public offering ("IPO") on November 7, 2012, refer to Southcross Energy LLC and its consolidated subsidiaries, unless otherwise specifically noted. References in this Form 10-K to the Partnership, when used for periods beginning at or following our IPO, refer collectively to the Partnership and its consolidated subsidiaries. Southcross Energy LLC and its subsidiaries are controlled through investment funds and entities associated with Charlesbank Capital Partners, LLC ("Charlesbank"). Southcross Energy LLC holds all of the equity interests in Southcross Energy Partners GP, LLC, a Delaware limited liability company and our general partner (“General Partner”).
	Initial Public Offering
	On November 7, 2012, we completed our initial public offering (the "IPO"). As the series of transactions described in Note 11 relate to entities under common control, these consolidated financial statements reflect the assets, liabilities, statements of operations and cash flows of us beginning November 7, 2012 and Southcross Energy LLC as of and for the periods ending prior to November 7, 2012.
	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 three gas processing plants, two fractionation plants and approximately 2,740 miles of pipeline. Our South Texas assets are located in or near the Eagle Ford shale region. We are headquartered in Dallas, Texas and our operations are managed as and presented in one reportable segment.
	Segments
	Our chief operating decision-maker is our Chief Executive Officer who reviews financial information presented on a consolidated basis in order to make decisions about resource allocations and assess our performance. 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 a one reportable segment.

BASIS_OF_PRESENTATION

BASIS OF PRESENTATION	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
BASIS OF PRESENTATION	'
	Basis of Presentation
	The accompanying consolidated financial statements and related notes present the consolidated balance sheets as of December 31, 2013 and 2012 and the consolidated statements of operations, consolidated statements of comprehensive income (loss), consolidated statements of cash flows and changes in partners' capital and members' equity for the years ended December 31, 2013, 2012 and 2011. As a result of our IPO, there was no change in the accounting basis of the contributed net assets of Southcross Energy LLC. Information included in these financial statements and related notes are presented as if we and Southcross Energy LLC were the same entity, except with respect to associated changes in capitalization as described in Note 11.
	The accompanying consolidated financial statements were prepared in accordance with accounting principles generally accepted in the U.S. ("GAAP") and in accordance with the rules and regulations of the U.S. Securities and Exchange Commission ("SEC"). Our consolidated financial statements include the accounts of Southcross and its 100% owned subsidiaries. We eliminate all intercompany balances and transactions in preparing consolidated financial statements.
	Principles of Consolidation
	We consolidate entities when we have the ability to control or direct the operating and financial decisions of the entity or when we have a significant interest in the entity that gives us the ability to direct the activities that are significant to that entity. The determination of our ability to control, direct or exert significant influence over an entity involves the use of judgment. We do not have ownership in any variable interest entities.
	Use of Estimates
	The preparation of the consolidated financial statements in conformity with GAAP requires management to make various estimates and assumptions that may affect the amounts of assets and liabilities, disclosures of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the period. Actual results may differ from those estimates.
	Revenue Recognition
	Using the revenue recognition criteria of persuasive evidence of an exchange arrangement exists, delivery has occurred or services have been rendered and the price is fixed or determinable, we record natural gas and NGL revenue in the period when the physical product is delivered to the customer and in an amount based on the pricing terms of an executed contract. Our transportation, compression, processing, fractionation and other revenue is recognized in the period when the service is provided and includes our fee-based service revenue. In addition, collectability is evaluated on a customer-by-customer basis. New and existing customers are subject to a credit review process, which evaluates the customers' financial position and their ability to pay.
	Our sale and purchase arrangements are primarily accounted for on a gross basis in the statements of operations. These transactions are contractual arrangements that establish the terms of the purchase of natural gas or NGLs at a specified location and the sale of natural gas or NGLs at a different location on the same or on another specified date. These transactions require physical delivery and transfer of the risk and reward of ownership are evidenced by title transfer, assumption of environmental risk, transportation scheduling, credit risk and counterparty nonperformance risk.
	We derive revenue in our business from the following types of arrangements:
	•	Fixed-Fee.  We receive a fixed-fee per unit of natural gas volume that we gather at the wellhead, process, treat, compress and/or transport for our customers, or we receive a fixed-fee per unit of NGL volume that we fractionate. Some of our arrangements also provide for a fixed-fee for guaranteed transportation capacity on our systems.
	•	Fixed-Spread.  Under these arrangements, we purchase natural gas and NGLs from producers or suppliers at receipt points on our systems at an index price plus or minus a fixed price differential and sell these volumes of natural gas and NGLs at delivery points off our systems at the same index price, plus or minus a fixed price differential. By entering into such back-to-back purchases and sales, we are able to mitigate our risk associated with changes in the general commodity price levels of natural gas and NGLs. We remain subject to variations in our fixed-spreads to the extent we are unable to precisely match volumes purchased and sold in a given time period or are unable to secure the supply or to produce or market the necessary volume of products at our anticipated differentials to the index price.
	•	Commodity-Sensitive.  In exchange for our processing services, we may remit to a customer a percentage of the proceeds from our sales, or a percentage of the physical volume, of residue natural gas and/or NGLs that result from our natural gas processing, or we may purchase NGLs from customers at set fixed NGL recoveries and retain the balance of the proceeds or physical commodity for our own account. These arrangements are generally combined with fixed-fee and fixed-spread arrangements for processing services and, therefore, represent only a portion of a processing contract's value. The revenues we receive from these arrangements directly correlate with fluctuating general commodity price levels of natural gas and NGLs and the volume of NGLs recovered relative to the fixed recovery obligations.
	Long-Lived Assets
	Our property, plant and equipment is recorded at its original cost of construction or, upon acquisition, at fair value of the assets acquired. For assets we construct, we capitalize direct costs, such as labor and materials, and indirect costs, such as overhead and the cost of financing construction. Costs associated with obtaining rights of way agreements and easements to facilitate the building and maintenance of new pipelines are capitalized and depreciated over the life of the associated pipeline. We capitalize major units of property replacements or improvements and expense minor items. We use the straight-line method to depreciate property, plant and equipment over the estimated useful lives of the assets. We depreciate leasehold improvements and capital lease assets over the shorter of the life of the asset or the life of the lease. Maintenance and repairs are charged directly to expense.
	Our intangible assets consist of acquired long-term supply and gas gathering contracts. We amortize these contracts on a straight-line basis over the 30-year expected useful lives of the contracts.
	Impairment of Long-Lived Assets
	We evaluate our long-lived assets, which include finite-lived intangible assets, for impairment when events or circumstances indicate that their carrying values may not be recoverable. These events include, but are not limited to, market declines that are believed to be other than temporary, changes in the manner in which we intend to use a long-lived asset, decisions to sell an asset and adverse changes in the legal or business environment such as adverse actions by regulators. If an event occurs, we evaluate the recoverability of our carrying value based on the long-lived asset's ability to generate future cash flows on an undiscounted basis. If the undiscounted cash flows are not sufficient to recover the long-lived asset's carrying value, or if we decide to sell a long-lived asset or group of assets, we adjust the carrying values of the asset downward, if necessary, to their estimated fair value. Our fair value estimates are generally based on assumptions market participants would use, including market data obtained through the sales process or an analysis of expected discounted cash flows. At December 31, 2013, 2012 and 2011, we have not recorded an impairment of long-lived assets.
	Capitalization of Interest Cost
	We capitalize interest on projects during their construction period. Once a project is placed in service, capitalized interest, as a component of the total cost of the construction, is depreciated over the estimated useful life of the asset constructed.
	We incurred the following interest costs (in thousands):
		Year Ended December 31,
		2013			2012			2011
	Total interest costs	$	14,047		$	12,035		$	7,157
	Capitalized interest included in property, plant and equipment, net	(1,457		)	(6,268		)	(1,809		)
	Interest expense	$	12,590		$	5,767		$	5,348
	Cash and Cash Equivalents
	We consider all short term investments with an original maturity of three months or less to be cash equivalents. At December 31, 2013 and 2012, except for amounts held in bank accounts to cover current payables, all of our cash equivalents were invested in short-term money market instruments.
	Allowance for Doubtful Accounts
	In evaluating the collectability of our accounts receivable, we perform ongoing credit evaluations of our customers and adjust payment terms based upon payment history and each customer's current creditworthiness, as determined by our review of such customer's credit information. We extend credit on an unsecured basis to many of our customers. At December 31, 2013 and 2012, we have recorded no allowance for uncollectible accounts receivable.
	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 consolidated balance sheets. Changes in deferred financing costs are as follows (in thousands):
		Year Ended December 31,
		2013			2012
	Deferred financing costs, January 1	$	4,385		$	2,154
	Capitalization of deferred financing costs (1)	2,139			5,178
	Less:
	Write off of deferred financing costs (1)(2)	—			1,764
	Amortization of deferred financing costs	1,287			1,183
	Deferred financing costs, December 31	$	5,237		$	4,385
	___________________________________________________________________________
	(1) See Note 7.
	(2) Amounts are considered a portion of the net carrying value of the related debt and are expensed when accelerated as a component of a debt extinguishment or modifications accounted for as an extinguishment.
	Asset Retirement Obligations
	We evaluate whether any future asset retirement obligations ("AROs") exist and estimate the costs for such AROs for certain future events. An ARO will be recorded in the periods where we can reasonably determine the settlement dates or the period in which the expense is incurred and an estimated cost of the retirement obligation. Generally we do not have the intention of discontinuing the use of any significant assets or have a legal obligation to do so. Therefore, in these situations we do not have sufficient information to reasonably estimate any future AROs. However, during the year ended December 31, 2013, an asset retirement obligation of $0.5 million related to the discontinued use of an asset was recorded in operations and maintenance expense. This ARO is substantially complete and we do not expect significant additional costs. No AROs were recorded for the years ended December 31, 2012 or 2011.
	Environmental Costs and Other Contingencies
	We recognize liabilities for environmental and other contingencies when we have an exposure that indicates it is both probable that a liability has been incurred and the amount of loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue a liability for that amount. Where the most likely outcome cannot be estimated, a range of potential losses is established and no specific amount in that range is more likely than any other, the low end of the range is accrued. No amounts were recorded as of December 31, 2013 and 2012.
	Fair Value of Financial Instruments
	Accounting guidance requires the disclosure of the fair value of all financial instruments that are not otherwise recorded at fair value in the financial statements. At December 31, 2013 and 2012, financial instruments recorded at contractual amounts that approximate fair value include certain funds on deposit, accounts receivable, other receivables, and accounts payable and accrued liabilities. The fair values of such items are not materially sensitive to shifts in market interest rates because of the short term to maturity of these instruments (See Note 5).
	The fair value of the debt funded through our Credit Facility approximates its carrying amount as of December 31, 2013 and 2012 due primarily to the variable nature of the interest rate of the instrument. The fair value of the debt is considered a Level 2 fair value measurement (See Note 5).
	Derivative Instruments
	In our normal course of business, we enter into month-ahead swap contracts in order to hedge economically our exposure to certain intra-month natural gas index pricing risk. We manage our interest rate risk through interest rate swaps.
	Derivative financial instruments are recorded in the consolidated balance sheets at fair value, except for derivative contracts that we qualify for and for which we have elected the normal purchase or normal sale exceptions, which are not reflected in the consolidated balance sheets or statements of operations prior to accrual of the settlement. We present our derivative assets and liabilities on a net basis.
	If certain criteria are met, a derivative financial instrument may be designated as a fair value hedge or cash flow hedge. In March 2012, we entered into an interest rate swap to reduce the risks with respect to the variability of the interest rates under our Credit Facility. With the exception of these interest rate swaps, we did not have any other derivative financial instruments designated as fair value or cash flow hedges for accounting purposes during the years ended December 31, 2013, 2012 and 2011.
	The changes in fair value of cash flow hedges are deferred in accumulated other comprehensive loss, net of tax, to the extent the contracts are, or have been, effective as hedges, until the forecasted transactions impact earnings. We record the ineffective portion of changes in fair value of cash flow hedges immediately into earnings.
	On an ongoing basis, a derivative instrument designated as a cash flow hedge must be highly effective in offsetting changes in cash flows of the hedged item. If it is determined that the derivative instrument is not highly effective as a hedge, hedge accounting will be discontinued prospectively. Changes in fair value of the associated hedging instrument are then recognized immediately in earnings for the remainder of the contract term unless a new hedging relationship is designated. The assessment of effectiveness excludes counterparty default risk and our own non-performance risk. The effect of these valuation adjustments was immaterial for the years ended December 31, 2013 and 2012, respectively.
	Derivative financial instruments designated as cash flow hedges must have a high correlation between price movements in the derivative and the hedged item. If and when an acceptable level of correlation no longer exists, hedge accounting ceases and changes in fair value are recognized in our statements of operations. If it becomes probable that a forecasted transaction will not occur, we immediately recognize the related deferred gains or losses in our statements of operations. Changes in fair value of the associated hedging instrument are then recognized immediately in earnings for the remainder of the contract term unless a new hedging relationship is designated.
	The interest rate swap is designated as a cash flow hedge for accounting purposes and, thus, to the extent the cash flow hedge is effective, unrealized gains and losses are recorded to accumulated other comprehensive income (loss) and recognized in interest expense as the underlying hedged transactions (interest payments) are recorded. Any hedge ineffectiveness is recognized in interest expense immediately. We did not have any hedge ineffectiveness during the years ended December 31, 2013 and 2012. We have elected to present our commodity swaps net in the balance sheet. We did not have any cash collateral received or paid on our commodity swaps as of December 31, 2013.
	For our derivative financial instruments that have not been designated as cash flow hedges for accounting purposes, changes in such instruments' fair values are recognized currently in earnings. We do not hold or issue financial instruments or derivative financial instruments for trading purposes. See Note 5.
	Unit-Based Compensation
	Unit-based awards which settle in common units are classified as equity and are recognized in the financial statements over the vesting period at their grant date fair value. Unit-based awards which settle in cash are classified as liabilities and remeasured at every balance sheet date through settlement, such that the vested portion of the liability is adjusted to reflect its revised fair value through compensation expense. Currently, all awards granted under the long-term incentive plan will be settled in common units. Compensation expense associated with unit-based awards, adjusted for forfeitures, is recognized evenly from the date of the grant over the vesting period within general and administrative expenses on our consolidated statements of operations.
	Income Taxes
No provision for federal or state income taxes is included in our statements of operations as such income is taxable directly to our partners. Each partner is responsible for its share of federal and state income tax. Net earnings for financial statement purposes may differ significantly from taxable income reportable to each partner as a result of differences between the tax basis and financial reporting basis of assets and liabilities.
We are responsible for our portion of the Texas margin tax that is included in Southcross Energy LLC's consolidated Texas franchise tax return. Our current tax liability will be assessed based on the gross revenue apportioned to Texas. The margin tax qualifies as an income tax under GAAP, which requires us to recognize the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis. For the years ended December 31, 2013 and 2012, there were no material temporary differences.
On September 13, 2013, the U.S. Department of the Treasury and IRS issued the final and re-proposed tangible property regulations effective for tax years beginning January 1, 2014. We determined that the provisions of these regulations and it will not impact our financial statements.
Uncertain Tax Positions
We evaluate the uncertainty in tax positions taken or expected to be taken in the course of preparing our consolidated financial statements to determine whether the tax positions are more likely than not of being sustained by the applicable tax authority. Tax positions deemed not to meet the more likely than not threshold would be recorded as a tax benefit or expense in the current year. We believe that there are no uncertain tax positions and that no provision for income tax is required for these consolidated financial statements.
Earnings per Unit
Net income (loss) per unit is calculated under the two-class method of computing earnings per unit when participating or multiple classes of securities exist. Under this method, undistributed earnings or losses for a period are allocated based on the contractual rights of each security to share in those earnings as if all of the earnings for the period had been distributed.
Basic net income (loss) per unit excludes dilution and is computed by dividing net income (loss) attributable to limited partner common units by the weighted average number of limited partner common units outstanding during the period. Paid-in kind distributions and valuation adjustments to maximum redemption value of the Series A convertible preferred units are excluded from income available to common units in the calculation of basic earnings per unit. Dilutive net income (loss) per unit reflects potential dilution from the potential issuance of limited partner common units. Dilutive net income (loss) per unit is calculated using the treasury stock method. It is computed by dividing net income (loss) attributable to limited partner common units by the weighted average number of limited partner common units outstanding during the period increased by the number of additional limited partner common units that would have been outstanding if the dilutive potential limited partner common units had been issued.
New Accounting Pronouncements
Accounting standard-setting organizations frequently issue new or revised accounting rules. We regularly review all new pronouncements to determine their impact, if any, on our financial statements.
In January 2013, the FASB issued an accounting standards update on “Disclosures About Offsetting Assets and Liabilities.” This update requires enhanced disclosures regarding the effect or potential effect of netting arrangements on our financial position by improving information about financial instruments and derivative instruments that are either offset in the balance sheet or are subject to an enforceable master netting arrangement or similar agreement, irrespective of whether they are offset. The disclosures are required to be adopted retroactively. We adopted this standard effective January 1, 2013, which did not have a material impact on our financial statements.
In February 2013, the FASB issued an accounting standards update on "Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income." This update requires that we report reclassifications out of accumulated other comprehensive income and their effect on net income by component or financial statement line effective for our quarterly filing for the three months ended March 31, 2013. We adopted this standard effective January 1, 2013, which did not have a material impact on our financial statements.

LIQUIDITY_CONSIDERATIONS_AND_E

LIQUIDITY CONSIDERATIONS AND EQUITY OFFERINGS LIQUIDITY CONSIDERATIONS AND EQUITY OFFERINGS	12 Months Ended
	Dec. 31, 2013
Capitalization, Long-term Debt and Equity [Abstract]	'
LIQUIDITY CONSIDERATIONS AND EQUITY OFFERINGS	'
	LIQUIDITY CONSIDERATIONS AND EQUITY OFFERINGS
	We believe we have and will continue to have sufficient liquidity as the Credit Facility with Wells Fargo, N.A. and a syndicate of lenders, as amended (our "Credit Facility") provides us with what we consider attainable covenants that will allow us to operate our business and continue to meet our commitments. As of December 31, 2013, we had $0.1 million of borrowing capacity under our Credit Facility. Southcross Energy LLC had $30.1 million of cash which has been made available to us for deposit into a collateral account of our General Partner (the "Collateral Account") to support subsequent additional borrowings.
	Amended Senior Secured Credit Facility
	During the fourth quarter 2012 and into the first quarter 2013 we encountered operational challenges including the January 2013 fire at our Gregory facility and contractual disputes with a former third-party processor. These items impacted our operating results adversely and resulted in the need to amend our Credit Facility.
	On March 27, 2013 and April 12, 2013, we entered into the first amendment (the "First Amendment") and second amendment (the "Second Amendment", collectively the "Amendments"), respectively, to our Credit Facility. As a result of the Amendments, our letters of credit sublimit was reduced from $75.0 million to $50.0 million and our available credit was reduced from $350.0 million to $250.0 million, plus the sum of any amounts placed on deposit in the Collateral Account, plus letters of credit outstanding The Second Amendment provided more favorable financial covenants until we give notice under the amended Credit Facility that we have achieved a Target Leverage Ratio (as defined in the Second Amendment) of 4.25 to 1.00 for one quarter or 4.50 to 1.00 for two consecutive quarters, calculated excluding the benefit of cash on deposit in the Collateral Account and any equity cure amounts (the "Target Leverage Test").
	As a condition to the Amendments, Southcross Energy LLC and our General Partner deposited into the Collateral Account a total of $40.0 million, which was required to be contributed to us in the second quarter of 2013 in exchange for Series A convertible preferred units (the "Series A Preferred Units"). The Series A Peferred Units are entitled to quarterly distributions of in-kind Series A Preferred Units for at least the first four full quarters following the issue date until the Target Leverage Test has been satisfied (see Note 7), at which time the board of directors of our General Partner may elect to begin paying quarterly distributions in cash. Additionally, Southcross Energy LLC and our General Partner agreed to deposit and has deposited into the Collateral Account the proceeds they received from cash distributions on units in us that are attributable to the each of the remaining quarters in 2013. As of December 31, 2013, the Collateral Account has $17.4 million on deposit.
	On January 29, 2014, in connection with the offering of additional common units, we entered into the third amendment (the "Third Amendment") to our Credit Facility. Pursuant to the Third Amendment, we may acquire a specified target entity or its assets, and make certain capital expenditures with respect to the extension of the Partnership’s pipeline systems located in McMullen County, Texas by approximately 90 miles (See Note 7). Also, under the terms of the Third Amendment to our Credit Facility, we amended our Consolidated Total Leverage Ratio (as defined in our Credit Facility) covenant in our Credit Facility to decrease automatically our “Maximum Adjusted Consolidated Total Leverage Ratio” (as defined in our Credit Facility) to 5.75 to 1.00.
	Public Offering of Common Units
	In February 2014, we completed the offering of 9,200,000 additional common partnership units under our previously effective “shelf” registration statement, generating $148.8 million in proceeds, before estimated expenses related to the offering of $0.4 million.
	Under the shelf registration process, we may over time, in one or more offerings, offer and sell any combination of the securities described in the prospectus, and the selling unitholders may, over time, in one or more offerings, offer and sell common units representing limited partner interests in us. We, together with Southcross Energy Finance Corp., may offer and sell debt securities described in the prospectus. Southcross Energy Finance Corp. may act as co-issuer of the debt securities, and certain of our direct or indirect subsidiaries may guarantee any debt securities offered, if and to the extent identified in the related prospectus supplement. The aggregate initial offering price of all securities sold by us under this prospectus will not exceed $675.0 million (See Note 11).
	We plan to use the net proceeds from the offering to fund the recently announced construction of our new pipeline extending into Webb County, TX and for general partnership purposes, including future permitted acquisitions. Pending such use, we temporarily repaid borrowings under our Credit Facility in February 2014, which we will redraw to fund the construction of the new pipeline (See Note 11).
	Private Placement of Series A Preferred Units
	As further discussed in Note 10, on April 12, 2013, to satisfy our requirements under our Credit Facility as discussed above, we entered into a Series A Preferred Unit 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 Series A Preferred Unit in a privately negotiated transaction (the "Private Placement") during the second quarter of 2013. The Private Placement resulted in proceeds to us of $39.2 million. We also received a $0.8 million capital contribution from our General Partner to maintain its 2.0% general partner interest in us.

ACQUISITIONS

ACQUISITIONS	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
ACQUISITIONS	'
	ACQUISITIONS
	Enterprise Alabama Intrastate, LLC
	Southcross Energy LLC acquired Enterprise Alabama Intrastate, LLC ("EAI") from Enterprise GTM Holdings L.P. for $21.8 million on September 1, 2011. EAI owned 388 miles of 2 to 16 inch natural gas pipeline assets located in northwest and central Alabama, and provided gathering, transportation and compression services and engaged in the purchase and sale of natural gas. EAI's identifiable assets acquired and liabilities assumed were recorded based upon the fair values determined on the date of acquisition.
	The fair values of the EAI property, plant and equipment were determined based upon assumptions related to expected future cash flows, discount rates and asset lives using currently available information. Southcross Energy LLC 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.
	Southcross Energy LLC completed its assessment of the fair value of the assets acquired and liabilities assumed as of March 31, 2012 and determined the consideration given was equal to the fair value of net assets acquired. As a result, no goodwill was recorded.
	The reconciliation of the fair value of the assets acquired and liabilities assumed related to the EAI purchase price was as follows (in thousands):
	Purchase Price—Cash	$	21,777
	Current assets	3,374
	Property, plant, and equipment	19,300
	Intangible assets	1,700
	Total assets acquired	24,374
	Current liabilities assumed	2,597
	Net identifiable assets acquired	$	21,777
	Southcross Energy LLC attributed $1.7 million to intangible assets associated with long-term supply and gathering contracts assumed in the acquisition (See Note 6).
	In the third quarter of 2011, Southcross Energy LLC expensed $0.2 million of transaction costs associated with the acquisition of EAI. These costs are reported within general and administrative expenses.
	The following unaudited pro forma financial information of our year ended December 31, 2011 assumes that the EAI acquisition occurred on January 1, 2010 and includes adjustments for income from operations, including depreciation and amortization, as well as the effects of financing the acquisition (in thousands, except unit information):
		Year Ended
		December 31, 2011
		Southcross			Combined
	Total revenue	$	523,149		$	548,152
	Net income	7,539			7,789
	Net loss attributable to common unitholders	(8,145		)	(7,895		)
	Net loss per unit—(basic and diluted)	(6.79		)	(6.59		)
	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 September 1, 2011 through December 31, 2011, EAI contributed $11.0 million in revenues and $0.8 million in net income to Southcross Energy LLC's statements of operations.

EARNINGS_PER_LIMITED_PARTNER_U

EARNINGS PER LIMITED PARTNER UNIT AND DISTRIBUTIONS	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
EARNINGS PER LIMITED PARTNER UNIT AND DISTRIBUTIONS	'
	PER LIMITED PARTNER UNIT AND DISTRIBUTIONS
	Earnings Per Unit of the Partnership
	The following is a reconciliation of net loss attributable to limited partners and the limited partner units used in the basic and diluted earnings per unit calculations for the years ended December 31, 2013 and 2012 (in thousands, except per unit data):
	Allocation of Net loss
		Year ended				Year ended
		December 31, 2013				December 31, 2012
	Net loss	$	(15,970	)		$	(4,488	)
	Series A Preferred Unit in-kind distribution and fair value adjustment	(1,670		)		—
	Net loss from January 1, 2012 through November 6, 2012	—				260
	Net loss attributable to partners	(17,640		)		(4,228		)
	General partner's interest (1)	(319		)		(85		)
	Limited partners' interest (1)
	Common	(8,683		)		(2,072		)
	Subordinated	(8,638		)		(2,071		)
	____________________________________________________________________________
	(1) General Partner's and Limited Partner's interest are calculated based on the allocation of net losses for the period, net of the allocation of general partner unit in-kind distributions, Series A Preferred Unit in-kind distributions and Series A Preferred Unit fair value adjustments.
	Common Units
		Year ended				Year ended
		December 31, 2013				December 31, 2012
	Interest in net loss	$	(8,683	)		$	(2,072	)
	Effect of dilutive units - numerator (1)	—				—
	Dilutive interest in net loss	$	(8,683	)		$	(2,072	)
	Weighted-average units - basic	12,224,997				12,213,713
	Effect of dilutive units - denominator (1)	—				—
	Weighted-average units - dilutive	12,224,997				12,213,713
	Basic and diluted net loss per common unit	$	(0.71	)		$	(0.17	)
	Subordinated Units
		Year ended				Year ended
		December 31, 2013				December 31, 2012
	Interest in net loss	$	(8,638	)		$	(2,071	)
	Effect of dilutive units - numerator (1)	—				—
	Dilutive interest in net loss	$	(8,638	)		$	(2,071	)
	Weighted-average units - basic	12,213,713				12,213,713
	Effect of dilutive units - denominator (1)	—				—
	Weighted-average units - dilutive	12,213,713				12,213,713
	Basic and diluted net loss per subordinated unit	$	(0.71	)		$	(0.17	)
	____________________________________________________________________________
	(1)Diluted net income per limited partner unit reflects the potential dilution that could occur if securities or agreements to issue common units, such as the conversion of Series A Preferred Units into common units or the awards under the long-term incentive plan, were exercised, settled or converted into common units. When it is determined that potential common units should be included in the diluted net income per limited partner unit calculation, the impact is reflected by applying the treasury stock method. Because we had a net loss for the year ended December 31, 2013 and 2012, 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. The weighted average units that were not included in the computation of diluted per unit amounts were 10,092 and 144,500 unvested awards granted under our long-term incentive plan for the year ended December 31, 2013 and 2012, respectively, and 1,233,117 Series A Preferred Units for the year ended December 31, 2013.
	The Series A Preferred Units are considered participating securities for purposes of the basic earnings per unit calculation during periods in which they receive cash distributions.  As we are required to pay in-kind distributions for the first four full quarters and continuing until the Target Leverage Option (See Note 7) has been achieved, the Series A Preferred Units have been excluded from the basic earnings per unit calculation. Earnings per unit accounting guidance also requires that adjustments in the fair value of preferred units be included within the determination of net income available to partners.
	Distributions
	Our Second Amended and Restated Agreement of Limited Partnership ("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. 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.
	Our General Partner is currently entitled to 2.0% of all distributions that we make prior to our liquidation. Our General Partner has the right, but not the obligation, to contribute a proportionate amount of capital to us to maintain its current general partner interest. Our General Partner's initial 2.0% interest in our distributions will be reduced if we issue additional limited partner units in the future and our General Partner does not contribute a proportionate amount of capital to us to maintain its 2.0% general partner interest.
	Our General Partner also currently holds incentive distribution rights that entitle it to receive increasing percentages, up to a maximum of 50%, of the cash we distribute from operating surplus in excess of $0.46 per unit per quarter. The maximum distribution of 50% includes distributions paid to our General Partner on its 2.0% general partner interest and assumes that our General Partner maintains its general partner interest at 2.0%. The maximum distribution of 50% does not include any distributions that our General Partner may receive on any limited partner units that it owns.
	The following table represents our distribution declared for the quarter ended December 31, 2013 and distributions paid for the previous periods (in thousands, except per unit data):
												Distributions
			Attributable to the		Per Unit							Limited Partners
	Payment Date		Quarter Ended		Distribution							Common				Subordinated			General Partner			Total
	2013
	February 14, 2014		December 31, 2013		$	0.4						$	8,581			$	4,885		$	289		$	13,755
	November 14, 2013		September 30, 2013		0.4							4,888				4,885			214			9,987
	August 14, 2013		June 30, 2013		0.35				(1	)		—				—			10			10
	August 14, 2013		June 30, 2013		0.2				(2	)		—				—			1			1
	August 14, 2013		June 30, 2013		0.4							4,890				4,886			199			9,975
	May 15, 2013		March 31, 2013		0.4							4,888				4,886			199			9,973
	2012
	14-Feb-13		31-Dec-12		0.24				(3	)		2,931				2,931			120			5,982
	____________________________________________________________________________
	(1) Per unit distribution of $0.35 corresponds to the minimum quarterly distribution of $0.40 per unit, or $1.60 on an annualized basis, pro-rated for the portion of the quarter following the issuance of 29,925 general partner units on April 12, 2013.
	(2) Per unit distribution of $0.20 corresponds to the minimum quarterly distribution of $0.40 per unit, or $1.60 on an annualized basis, pro-rated for the portion of the quarter following the issuance of 5,075 general partner units on May 15, 2013.
	(3) Per unit distribution of $0.24 corresponds to the minimum quarterly distribution of $0.40 per unit, or $1.60 on an annualized basis, pro-rated for the portion of the quarter following the closing of our IPO on November 7, 2012.
	In accordance with our long-term incentive plan ("LTIP"), we paid the distribution equivalent rights to holders of LTIP units that vested during year ended December 31, 2013 (See Note 13). On November 14, 2013, we paid an aggregate distribution of $63.8 thousand to the holders of the vested phantom 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 Credit Facility (See Note 7 and Note 10). Under the terms of our Partnership Agreement, we are 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 we have given notice under our Credit Facility that we have achieved the Target Leverage Ratio (See Note 7) and after the board of directors of our General Partner determines to begin paying quarterly distributions in cash.  In-kind distributions will be 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) or, beginning after four full quarters, such higher per unit rate as is paid in respect to our common units. For accounting purposes, these in-kind distributions are recorded at fair value based on the value of a common unit when accrued. Cash distributions will 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 receives a corresponding distribution of in-kind general partner units to maintain its 2.0% interest in us.
	The following table represents the paid in-kind (“PIK”) distribution earned for the quarter ended December 31, 2013 and PIK distributions for the previous periods (in thousands, except per unit and in-kind distribution units):
Payment Date		Attributable to the Quarter Ended		Per Unit Distribution						In-Kind Series A			In-Kind				In-Kind		In-Kind General Partner Distribution Value(3)
										Preferred Unit			Series A				Unit
										Distributions			Preferred				Distribution
										to Series A			Distributions				to General
										Preferred			Fair Value(3)				Partner
										Holders
2013
February 14, 2014		December 31, 2013		$	0.4					30,971			$	558			632		$	11
November 14, 2013		September 30, 2013		0.4						30,439			511				621		10
August 14, 2013		June 30, 2013		0.35				-1		22,276			512				454		10
August 14, 2013		June 30, 2013		0.2				-2		2,199			51				45		1
____________________________________________________________________________
(1) Per unit distribution of $0.35 corresponds to the minimum quarterly distribution of $0.40 per unit, or $1.60 on an annualized basis, pro-rated for the portion of the quarter following the issuance of 1,466,325 Series A Preferred Units and 29,925 general partner units on April 12, 2013.
(2) Per unit distribution of $0.20 corresponds to the minimum quarterly distribution of $0.40 per unit, or $1.60 on an annualized basis, pro-rated for the portion of the quarter following the issuance of 248,675 Series A Preferred Units and 5,075 general partner units on May 15, 2013.
(3) 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.
Earnings Per Common Unit of Southcross Energy LLC
A reconciliation of basic and diluted earnings per unit related to the Southcross Energy LLC common units is included in our consolidated statements of operations.
Southcross Energy LLC calculated earnings per common unit by first deducting the amount of cumulative returns on both the Redeemable Preferred and Preferred units from net income (loss), and dividing this amount by the weighted average number of vested common units (including both the vested Class A common units and Class B units). For periods presented in which Southcross Energy LLC units were outstanding, no unvested common units were included in the computation of the diluted per unit amount because all would have been antidilutive to the net loss per common unit holder. The amount of unvested common units that were not included in the computation of diluted per unit amounts were 143,220 units and 274,762 units for the periods ended November 6, 2012 and December 31, 2011, respectively.

FINANCIAL_INSTRUMENTS

FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2013
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, OTC swap contracts based upon natural gas price indices and interest rate swaps.
	•	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.
	Derivative Financial Instruments
	Interest Rate Swaps
	We manage a portion of our interest rate risk through interest rate swaps. In March 2012, we terminated an interest rate cap contract and entered into an interest rate swap contract with Wells Fargo, N.A. to reduce the risk associated with the variability of interest rates for our term loan borrowings. The interest rate swap has a notional value of $150.0 million, and a maturity date of June 30, 2014. We receive a floating rate based upon one-month LIBOR and pay a fixed rate under the interest rate swap of 0.54%.
	The fair value of our interest rate swap is determined based on a discounted cash flow method using the contractual terms of the swap. The floating coupon rate is based on observable rates consistent with the frequency of the interest cash flows. As of December 31, 2013 and 2012, the current portion of the interest rate swap liability of $0.3 million was included within other current liabilities. As of December 31, 2012, the non-current portion of the interest rate swap liability of $0.3 million was included within other non-current liabilities. As of December 31, 2013, there was no non-current portion of the interest rate swap liability.
	The fair value of the interest rate swap liabilities were as follows (in thousands):
		Significant Other Observable Inputs (Level 2)
		Fair value measurement as of
		December 31, 2013			December 31, 2012
	Interest rate swap liability	$	263		$	638
	The interest rate swap is designated as a cash flow hedge for accounting purposes and, thus, to the extent the cash flow hedge is effective, unrealized gains and losses are recorded to accumulated other comprehensive income/(loss) and recognized in interest expense as the underlying hedged transactions (interest payments) are recorded. Any hedge ineffectiveness is recognized in interest expense immediately. We did not have any hedge ineffectiveness during the years ended December 31, 2013 and 2012.
	The effect of the interest rate swap designated as a cash flow hedge in our statements of changes in partners’ capital and members’ equity and comprehensive income/(loss) were as follows (in thousands):
		Year ended December 31,
		2013			2012			2011
	Change in value recognized in other comprehensive loss - effective portion	$	(148	)	$	(745	)	$	—
	Loss reclassified from accumulated other comprehensive loss to interest expense	$	415		$	268		$	—
	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. Based on current interest rates, we estimate that approximately $0.3 million of hedging losses related to the interest rate swap contract will be reclassified from accumulated other comprehensive income (loss) into statements of operations within the next 12 months.
	The amounts recognized in interest expense associated with derivatives that are not designated as hedging instruments were as follows (in thousands):
		Year ended December 31,
		2013			2012			2011
	Unrealized loss on interest rate cap	$	—		$	141		$	21
	Realized loss on interest rate cap	$	108		$	82		$	147
	Commodity Swaps
	In our normal course of business, periodically we enter into month-ahead swap contracts to hedge our exposure to certain intra-month natural gas index pricing risk. The total volume of outstanding month-ahead swap contracts as of December 31, 2013 was 33,722 MMBtu per day. We had no outstanding month-ahead swap contracts as of December 31, 2012. 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. As of December 31, 2013, the fair value of $0.1 million was included within other current assets.
	We have elected to present our commodity swaps net in the balance sheet. We did not have any cash collateral received or paid on our commodity swaps as of December 31, 2013. The effect of offsetting in our balance sheet was as follows (in thousands):
			Other Current Assets		Other Current Liabilities
	Commodity Swaps
	Gross Amounts of Recognized Assets / (Liabilities)		140		(20	)
	Gross Amounts Offset in the Balance Sheet		(20	)	20
	Net Amount		120		—
	The realized and unrealized gain/(loss) on these derivatives, recognized in revenues in our statements of operations were as follows (in thousands):
		Year ended December 31,
		2013			2012			2011
	Realized gain/(loss) on derivatives	$	(659	)	$	(12	)	$	179
	Unrealized gain/(loss) on derivatives	120			—			—

LONGLIVED_ASSETS

LONG-LIVED ASSETS	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
LONG-LIVED ASSETS	'
	Property, Plant and Equipment
	Property, plant and equipment consist of the following (in thousands):
		Estimated	As of December 31,
		Useful Life	2013			2012
	Pipelines	30	$	344,721		$	250,177
	Gas processing, treating and other plants	15	254,133			221,594
	Compressors	7	20,030			19,241
	Rights of way and easements	15	20,729			20,729
	Furniture, fixtures and equipment	5	3,347			3,087
	Capital lease vehicles	5-Mar	1,396			—
	Total property, plant and equipment		644,356			514,828
	Accumulated depreciation and amortization		(79,908		)	(46,466		)
	Total		564,448			468,362
	Construction in progress		6,039			77,011
	Land and other		5,308			5,230
	Property, plant and equipment, net		$	575,795		$	550,603
	Depreciation is provided using the straight-line method based on the estimated useful life of each asset. Depreciation expense for the years ended December 31, 2013, 2012 and 2011 was $33.5 million, $19.0 million and $12.3 million, respectively.
	In January 2013, we shut down our Gregory facility to perform extensive turnaround maintenance activities and to connect additional equipment to enhance NGL recoveries.  As the turnaround maintenance was nearing completion, we experienced a fire at this facility.  In connection with the fire, we filed an insurance claim and have submitted approximately $4.6 million in costs to our insurance provider. The costs that have been submitted were deemed by us to be costs incurred to return the plant to service.  We have recovered $1.0 million from insurance for this loss during the second quarter of 2013 and believe it is probable that we will recover the remaining costs, less a $0.3 million deductible, under our insurance policies. We have also filed an insurance claim under our business interruption insurance policy as a result of the business interruption we experienced in connection with the fire at the Gregory facility. As of December 31, 2013, our business interruption claim is under review and the amount of proceeds to be received therefrom has not been determined.
	Intangible Assets
	Intangible assets of $1.6 million and $1.6 million as of December 31, 2013 and 2012, respectively, represent the unamortized value assigned to the long-term supply and gathering contracts assumed by us in the EAI acquisition. The majority of assumed contracts are life of lease, and we determined that the useful economic lives of the underlying producing leases were at least as long as the expected life of the acquired pipelines. These intangible assets are amortized on a straight-line basis over the 30-year expected useful lives of the contracts. Amortization expense in the consolidated financial statements presented and over the next five years related to intangible assets for the periods presented is not material.

LONGTERM_DEBT

LONG-TERM DEBT	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
LONG-TERM DEBT	'
	LONG-TERM DEBT
	Third Amendment to Credit Facility
	On January 29, 2014, we entered into the Third Amendment (the “Third Amendment”) to our Credit Facility.
	Pursuant to the Third Amendment, we may (a) acquire a specified target entity or its assets, provided that, among other things, the aggregate consideration paid by us in connection with such acquisition does not exceed $40.0 million and (b) make certain capital expenditures with respect to the addition to our pipeline systems by approximately 90 miles in Webb County, Texas, Dimmit County, Texas, and LaSalle County, Texas (the “Webb Pipeline”).
	In addition, the Third Amendment amends our Consolidated Total Leverage Ratio (as defined in our Credit Facility) covenant in our Credit Facility to decrease automatically our Maximum Adjusted Consolidated Total Leverage Ratio (as defined in our Credit Facility) to 5.75 to 1.00 as we have (a) received net cash proceeds in a specified amount pursuant to permitted equity offerings and (b) initiated construction of the Webb Pipeline in accordance with the terms of our Credit Facility.
	Long-Term Debt Overview
	Our long-term debt consisted of the following (in thousands):
		As of December 31,
		2013		2012
	Credit Facility, due November 2017	$	267,300	$	191,000
	Total	267,300		191,000
	Less:
	Current maturities of long-term debt	—		—
	Total long-term debt	$	267,300	$	191,000
	Our Credit Facility contains various covenants and restrictive provisions and requires maintenance of certain financial and operational covenants. As of December 31, 2013 and 2012, we were in compliance with all of our financial loan covenants. All of our assets are pledged as collateral under our Credit Facility. The terms of our Credit Facility contain customary covenants, including those that restrict our ability to make or limit certain payments, distributions, acquisitions, loans, or investments, incur certain indebtedness or create certain liens on its assets, consolidate or enter into mergers, dispose of certain of our assets, engage in certain types of transactions with its affiliates, enter into certain sale/leaseback transactions and modify certain material agreements.
	Borrowings under our Credit Facility bear interest at LIBOR plus an applicable margin or a base rate as defined in the respective credit agreements. Under the terms of our Credit Facility, the applicable margin under LIBOR borrowings was 4.50% and 3.25% at December 31, 2013 and 2012, respectively. The weighted-average interest rate for the year ended December 31, 2013 and 2012 was 4.44% and 3.95%, respectively.
	Under our Credit Facility, we have the ability to borrow $250.0 million plus an amount equal to the funds deposited into the Collateral Account and letters of credit outstanding. As of December 31, 2013, cash on deposit in the Collateral Account was $17.4 million. Our letters of credit outstanding were $31.3 million and $26.3 million as of December 31, 2013 and 2012, respectively. Our borrowings under our Credit Facility were $267.3 million and $191.0 million as of December 31, 2013 and 2012, respectively, and our remaining available capacity under our Credit Facility was $0.1 million as of December 31, 2013. As of December 31, 2013, Southcross Energy LLC had $30.1 million of cash which has been made available for deposit into the Collateral Account to support subsequent additional borrowings. For the year ended December 31, 2013 and 2012, our average outstanding borrowings were $243.9 million and $230.4 million and our maximum outstanding borrowings were $267.3 million and $270.0 million, respectively.
	Credit Facility
	In connection with the closing of our IPO, we entered into a $350.0 million senior secured Credit Facility with Wells Fargo Bank, N.A., and a syndicate of lenders. We utilized our Credit Facility to fund fees and expenses incurred in connection with our IPO and for the repayment of a portion of Southcross Energy LLC's debt under its credit agreement.
	Our Credit Facility matures on November 7, 2017, the fifth anniversary of our IPO closing date. We may utilize our Credit Facility for working capital requirements and capital expenditures, the purchase of assets, the payment of distributions, repurchase of units and for our general purpose. We believed it was unlikely that we would be in compliance with our financial covenants calculated for the quarter ended March 31, 2013, such that we negotiated with our lenders and secured more favorable financial covenants associated with our Credit Facility as further discussed below.
	On March 27, 2013, we entered into the First Amendment to our Credit Facility. As a result of the First Amendment, our letters of credit sublimit was reduced from $75.0 million to $31.5 million and our available credit was reduced from $350.0 million to $250.0 million, plus the sum of any amounts placed on deposit in the Collateral Account, plus letters of credit outstanding. As a condition to the First Amendment, our General Partner placed $10.0 million in the Collateral Account and that Collateral Account and the associated cash was pledged as collateral for the benefit of the lenders. Pursuant to the First Amendment, we were allowed to pay our quarterly cash distribution of available cash for the first quarter 2013 in an amount not to exceed $10.0 million on deposit in the Collateral Account. In connection with the First Amendment, we incurred $0.6 million in fees, which have been deferred and are being amortized over the remaining life of our Credit Facility.
	On April 12, 2013, we entered into the Second Amendment to our Credit Facility, which waived our defaults relating to financial covenants in our Credit Facility for the period ended March 31, 2013 and provided more favorable financial covenants until we give notice under our Credit Facility that we have achieved a consolidated total leverage ratio (the “Target Leverage Ratio”) of 4.25 to 1.00 for one quarter or 4.50 to 1.00 for two consecutive quarters, calculated excluding the benefit of cash on deposit in the Collateral Account and any equity cure amounts (the “Target Leverage Test”). The Target Leverage Test is not a required calculation under the Second Amendment, and can be calculated and elected at our option (the “Target Leverage Option”). Our available credit, excluding our letters of credit, continues to be subject to the availability limits described in the First Amendment.  In connection with the Second Amendment, we incurred $1.5 million in fees, which have been deferred and are being amortized over the remaining life of our Credit Facility.
	The Second Amendment provided for, among other things, the following:
	•	the lenders waived defaults relating to financial covenants for the quarter ended March 31, 2013;
	•	an increase in our letters of credit sublimit to $50.0 million;
	•	until we achieve the Target Leverage Ratio:
	◦	an increase in our interest rate to be LIBOR plus 4.50%. After achieving the Target Leverage Ratio our interest rate reverts to the original pricing grid of not more than LIBOR plus 3.25%;
	◦	a limit to our growth capital expenditures of $25.0 million for the last three quarters of 2013 and an additional $25.0 million for the 18 months ending June 30, 2015 (provided that if additional cash, as required under the Second Amendment, is placed in the Collateral Account, such expenditures may be increased to $28.0 million each period for the remaining three quarters of 2013 and the subsequent 18-months ending June 30, 2015);
	◦	distributions to our unitholders are effectively limited to our established minimum quarterly distribution of $0.40 per unit; and
	◦	our ability to make acquisitions is limited; and
	•	proceeds from any new equity issuances or asset sales are to be applied to reduce the then outstanding debt.
	Additionally, Southcross Energy LLC and our General Partner agreed to deposit into the Collateral Account proceeds received from cash distributions on our common units and subordinated units that they own and that are attributable to each calendar quarter in 2013.
	Pursuant to the Second Amendment, our General Partner and Southcross Energy LLC made an equity investment in us in an aggregate amount equal to $40.0 million in exchange for 35,000 General Partner units and 1,715,000 Series A Preferred Units, respectively. Distributions of the Series A Preferred Units are required to be paid-in kind for the first four full quarters following the issuance of the units and until the Target Leverage Test has been satisfied. Our total capital infusion of $40.0 million, from all sales of Series A Preferred Units and General Partner contributions was used to reduce borrowings under our Credit Facility (See Note 10).
	If we fail to meet the Target Leverage Test by June 30, 2014, all or a portion of the cash distributions we make to Southcross Energy LLC and our General Partner for the quarters ended June 30, 2013, September 30, 2013 and December 31, 2013 will be invested in us as additional paid-in kind equity securities until the Target Leverage Test has been satisfied. If, as of June 30, 2014, the Target Leverage Test is met, any funds then on deposit in the Collateral Account (other than equity cure amounts and amounts deposited in the Collateral Account to allow us to increase the amount of our capital expenditures) will be released to Southcross Energy LLC and our General Partner.
	The Second Amendment required us to have Consolidated EBITDA (as defined in our Credit Facility) of at least $9.0 million, for the quarter ended June 30, 2013, and we were not subject to the Maximum Adjusted Consolidated Total Leverage Ratio (as defined in the Credit Facility) for such quarter. The Second Amendment provides that until we satisfy the Target Leverage Ratio, we are allowed to calculate an adjusted consolidated total leverage ratio, which allows for the netting of total funded indebtedness with amounts on deposit in the Collateral Account, and we may not permit our adjusted consolidated total leverage ratio to exceed the ratio set forth below for the corresponding period (as provided in our Credit Facility):
		Maximum Adjusted Consolidated Total Leverage Ratio
	September 30, 2013	7.25 to 1.00
	December 31, 2013	6.75 to 1.00
	March 31, 2014	6.25 to 1.00
	June 30, 2014	5.25 to 1.00
	September 30, 2014	5.00 to 1.00
	December 31, 2014	4.75 to 1.00
	March 31, 2015 and thereafter	4.50 to 1.00
	For the quarter ended December 31, 2013 and September 30, 2013, our Maximum Adjusted Consolidated Total Leverage Ratio was approximately 5.3 to 1.00 and 6.5 to 1.00, respectively.
	If, for the calendar quarters ended on or before December 31, 2013, we failed to comply with the financial covenants of our Credit Facility ("Financial Covenant Default") we had the right (which could not be exercised more than two times) to cure such Financial Covenant Default by having Southcross Energy LLC and/or our General Partner deposit into the Collateral Account the amount required by the Second Amendment to cure such Financial Covenant Default.
	For the quarter ended June 30, 2013, the Second Amendment required us to have Consolidated EBITDA (as defined in our Credit Facility) of at least $9.0 million, and we were not subject to the Adjusted Consolidated Total Leverage Ratio (as defined in our Credit Facility) for such quarter.  As a result of our not meeting the Consolidated EBITDA covenant for the quarter ended June 30, 2013 we utilized our right to cure and Southcross Energy LLC deposited approximately $2.7 million into the Collateral Account on August 6, 2013, which was earlier than the date required under the Second Amendment.
	Our ability to fund expansion projects while our Credit Facility is in effect was limited to $25.0 million during the second through fourth quarters of 2013 and an additional $25.0 million in the subsequent 18-month period ending June 30, 2015, which can be increased to $28.0 million in each period if additional funds are placed into the Collateral Account. In October 2013, Southcross Energy LLC deposited an additional $3.0 million into the Collateral Account increasing our limit for 2013 expansion projects to $28.0 million.
	Upon satisfying the Target Leverage Ratio, beginning with the quarter ended September 30, 2013, the Second Amendment provides that we will not permit our Maximum Consolidated Total Leverage Ratio to exceed the ratio set forth below for the corresponding period (as provided in our Credit Facility):
		Maximum Consolidated
		Total Leverage Ratio
	September 30, 2013	4.75 to 1.00
	December 31, 2013 and thereafter	4.50 to 1.00
	As of December 31, 2013, we have not satisfied the Target Leverage Ratio, therefore the Maximum Consolidated Total Leverage Ratio is not applicable.
	The Second Amendment changed the minimum Consolidated Interest Coverage Ratio (as provided in our Credit Facility) to 2.25 to 1.00 for the quarters ended September 30, 2013 and December 31, 2013 and 2.50 to 1.00 for the quarters ending March 31, 2014 and thereafter. For the quarter ended December 31, 2013, our Consolidated Interest Coverage Ratio was approximately 3.13 to 1.00.

COMMITMENTS_AND_CONTINGENT_LIA

COMMITMENTS AND CONTINGENT LIABILITIES	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENTS AND CONTINGENT LIABILITIES	'
	COMMITMENTS AND CONTINGENT LIABILITIES
	Legal Matters
	On March 5, 2013, our subsidiary filed suit against Formosa Hydrocarbons Company, Inc. (“Formosa”).  The lawsuit seeks recoveries of losses that we believe our subsidiary experienced as a result of the failure of Formosa to perform certain of its 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 affiliate 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. We believe the counterclaims are without merit and our subsidiary will defend itself vigorously against the counterclaims while continuing to pursue our own claims. We cannot predict the outcome of such litigation or the timing of any related recoveries or payments.
	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. There currently are no such pending proceedings to which we are a party that our management believes will have a material adverse effect on our statements 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 statements 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 statements of operations, cash flows or financial condition.
	Commitments and Purchase Obligations
	Capital Leases
	We have auto leases classified as capital leases that are recorded in other current liabilities and other non-current liabilities in our consolidated balance sheet as of December 31, 2013. The lease termination dates of the agreements vary from 2013 until 2017. We recorded amortization expense related to the capital leases of $0.5 million for the year ended December 31, 2013. Capital leases entered into during the year ended December 31, 2013 were $1.4 million. We had no capital leases during 2012.
	Operating Leases
	We maintain operating leases in the ordinary course of our business activities. These leases include office buildings and other operating facilities and equipment. The termination dates of the agreements vary from 2013 until 2016. Expenses associated with operating leases were $1.5 million, $2.2 million, and $1.5 million for the years ended December 31, 2013, 2012 and 2011, respectively.
	Future Minimum Lease Payments
	Future minimum annual rental commitments under our capital and operating leases at December 31, 2013 were as follows (in thousands):
	Years Ending December 31,	Capital Leases			Operating Leases
	2014	$	505		$	583
	2015	295			555
	2016	105			455
	2017	34			299
	2018	—			—
	Total future payments	939			$	1,892
	Less: Imputed interest	(78		)
	Future lease payments	$	861
	Purchase Commitments
	At December 31, 2013, we had commitments of approximately $0.9 million to purchase equipment related to our capital 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_PART

TRANSACTIONS WITH RELATED PARTIES	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
TRANSACTIONS WITH RELATED PARTIES	'
	TRANSACTIONS WITH RELATED PARTIES
	Charlesbank
	Historically, Charlesbank provided certain management services to Southcross Energy LLC pursuant to a management services agreement (the "Charlesbank Agreement") which specified an annual management fee of $0.6 million. Southcross Energy LLC received services under the Charlesbank Agreement up to our IPO. Subsequent to our IPO, we did not receive any further services under this agreement, as the Charlesbank Agreement terminated with our IPO.
	For the years ended December 31, 2012 and 2011, Southcross Energy LLC incurred management fees of $0.5 million and $0.6 million, respectively, for services received and incurred associated expenses of $68,000 and $109,000, respectively under the Charlesbank Agreement. Services fees and expenses under the Charlesbank Agreement are recognized in general and administrative expenses in our consolidated statements of operations. After February 7, 2012 the payment of fees and expenses under the Charlesbank Agreement was not allowed under the Credit Agreement. Therefore, no payments for services provided after that date were made under the Charlesbank Agreement.
	The current board of directors of our General Partner includes three persons affiliated with Charlesbank and three outside directors. All of these directors are compensated equally for similar responsibilities and reimbursed for expenses incurred for their services to us. For the year ended December 31, 2013, we paid Charlesbank $0.5 million for director fees and related expenses which are reflected in general and administrative expenses in our consolidated statements of operations.
	Southcross Energy LLC and 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, which began on January 1, 2013 in accordance with our Partnership Agreement. During the year ended December 31, 2013, we incurred expenses of $24.8 million related to these reimbursements, which are reflected in operating expenses in our consolidated statements of operations.
	During the second quarter of 2013, to satisfy our requirements under our Credit Facility, we entered into a Purchase Agreement (as defined below) 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 Series A Preferred Unit, in a privately negotiated transaction (See Note 10). After the Series A Preferred Units issuance during the second quarter of 2013, Southcross Energy LLC sold 1,500,000 of the units to third parties. As of December 31, 2013, Southcross Energy LLC holds 221,884 Series A Preferred Units.
	See Note 7 for discussion of the Collateral Account held by our General Partner and cash made available for deposit by Southcross Energy LLC.
	Wells Fargo Bank, N.A.
	We entered into the credit agreements with syndicates of financial institutions and other lenders. These syndicates included affiliates of Wells Fargo Bank, N.A., an affiliate of which is a member of the investor group (See Note 12). 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. Total fees paid, excluding interest, to affiliates of Wells Fargo, N.A., and its affiliates were $1.8 million, $5.9 million and $1.0 million for the years ended December 31, 2013, 2012, and 2011, respectively.

SERIES_A_CONVERTIBLE_PREFERRED

SERIES A CONVERTIBLE PREFERRED UNITS SERIES A CONVERTIBLE PREFERRED UNITS	12 Months Ended
	Dec. 31, 2013
Statement of Partners' Capital [Abstract]	'
SERIES A CONVERTIBLE PREFERRED UNITS	'
	SERIES A CONVERTIBLE PREFERRED UNITS
	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 during the second quarter of 2013 for a cash purchase price of $22.86 per unit. Southcross Energy LLC sold 1,500,000 of these Series A Preferred Units to third parties during the second quarter of 2013.
	Our total capital infusion of $40.0 million, from all sales of Series A Preferred Units and General Partner capital contributions, was used to reduce borrowings under our Credit Facility (See Note 7). The Private Placement of Series A Preferred Units resulted in proceeds to us of $39.2 million. We also received a $0.8 million capital contribution from our General Partner to maintain its 2.0% general partner interest in us.
	Applicable accounting guidance related to the Series A Preferred Units requires that equity instruments with redemption features that are redeemable at the option of the holder be classified outside of permanent equity.  The change of control rights associated with the Series A Preferred Units requires the units to be classified outside of permanent equity.  The Series A Preferred Units have been adjusted to maximum redemption value in accordance with the change of control rights provision of our Partnership Agreement in the event that maximum redemption value exceeds the fair value of the unit at the issuance date. The distributions and adjustments to maximum redemption value associated with the Series A Preferred Units of $1.7 million have been included in the calculation of partners’ capital and earnings per unit for the year ended December 31, 2013. Additionally, none of the identified embedded derivatives relating to the terms of the Series A Preferred Units require bifurcation, as each embedded derivative was determined to be clearly and closely related to the host contract.
	Voting Rights: The Series A Preferred Units are a class of voting equity security that ranks senior to all of our other classes or series of equity securities with respect to distribution rights and rights upon liquidation.  The Series A Preferred Units have voting rights identical to the voting rights of the common units and vote with the common units as a single class, such that each Series A Preferred Unit (including each Series A Preferred Unit issued as an in-kind distribution, discussed below) is entitled to one vote for each common unit into which such Series A Preferred Unit is convertible on each matter with respect to which each common unit is entitled to vote.
	Distribution Rights: Holders of Series A Preferred Units are entitled to quarterly distributions of in-kind Series A Preferred Units for the first four full quarters following the issue date of those units and continuing thereafter until the board of directors of our General Partner determines to begin paying quarterly distributions in cash, and thereafter in cash. The board of directors of our General Partner may not elect to begin paying quarterly distributions on the Series A Preferred Units in cash until we have exercised the Target Leverage Option (pursuant to the Second Amendment) under our Credit Facility. In-kind distributions will be made 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) or, beginning after four full quarters, such higher per unit rate as is paid in respect of our common units. Cash distributions will equal the greater of $0.40 per unit per quarter or the quarterly distribution paid with respect to each common unit. The fair value of an in-kind distribution is calculated as required, based on the common unit price at the quarter end date for the period attributable to the distribution.
	Conversion Rights: Beginning on the later of January 1, 2015 and the date we exercise the Target Leverage Option (pursuant to the Second Amendment), Series A Preferred Units (including Series A Preferred Units issued as in-kind distributions) will be convertible into common units on a one-for-one basis, except that conversion will be prohibited to the extent that it would cause (on a pro forma basis) our estimated quarterly distributions over any of the succeeding four quarters to exceed our total distributable cash flow in that quarter.
	Additionally, on the later of January 1, 2015 and the date we exercise the Target Leverage Option (pursuant to the Second Amendment), we will have the right at any time to convert all or some of the Series A Preferred Units (including Series A Preferred Units issued as in-kind distributions) then outstanding into common units if (i) the daily volume-weighted average trading price of the common units on the national securities exchange on which the common units are listed or admitted to trading for the trailing 30-trading-day period before our notice of conversion is greater than 130% of the unit purchase price for the Series A Preferred Units, (ii) the average daily trading volume of common units on the securities exchange exceeds 40,000 common units for those 30 trading days and (iii) the conversion would not cause (on a pro forma basis) our estimated quarterly distributions over any of the succeeding four quarters to exceed our total distributable cash flow in that quarter.  Further, the Series A Preferred Units will be convertible into common units based on an exchange ratio of 110% of the Series A Preferred Units if a third party acquires majority ownership control of our General Partner or we sell substantially all of our assets, in either case before January 1, 2015.
	PARTNERS' CAPITAL AND MEMBERS' EQUITY
	Shelf Registration Statement and Public Offering
	On November 29, 2013, we filed a Registration Statement on Form S-3 with the U.S. Securities and Exchange Commission (the "SEC") using a "shelf" registration process. Under the shelf registration process, we may over time, in one or more offerings, offer and sell any combination of the securities described in the prospectus, and the selling unitholders may, over time, in one or more offerings, offer and sell common units representing limited partner interests in us. We, together with Southcross Energy Finance Corp., may offer and sell debt securities described in the prospectus. Southcross Energy Finance Corp. may act as co-issuer of the debt securities, and certain direct or indirect subsidiaries of us may guarantee any debt securities offered, if and to the extent identified in the related prospectus supplement. The aggregate initial offering price of all securities sold by us under the prospectus will not exceed $675.0 million.
	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 $148.8 million, before estimated expenses related to the offering of $0.4 million. We plan to use the net proceeds from the offering to fund the recently announced construction of our new pipeline extending into Webb County, Texas and for general partnership purposes, including future permitted acquisitions. Pending such use, we temporarily repaid borrowings under our senior secured revolving credit facility with Wells Fargo, N.A. and a syndicate of lenders (as amended, our "Credit Facility"), which we will redraw to fund the construction of the new pipeline and for other general purposes.
	Partners' Capital
	On November 7, 2012, we completed our IPO. Through a series of transactions, Southcross Energy LLC contributed all of its operating subsidiaries (its net assets on a historical cost basis), excluding certain liabilities and all preferred units, and became the holding company of us. Southcross Energy LLC holds all of the equity interests in our General Partner, as well as all subordinated units and a portion of the common units of us. Subsequent to our IPO, we own Southcross Energy LLCs' operating subsidiaries. At the completion of our IPO, we received proceeds of approximately $168.0 million, net of underwriters' discounts and structuring fees. In connection with the full exercise of the underwriter's over-allotment option, which closed on November 26, 2012, our underwriters purchased 1,350,000 additional common units in us for approximately $25.2 million in proceeds, net of underwriters' and structuring fees; and we used the net proceeds of $25.2 million to reacquire 1,350,000 common units from Southcross Energy LLC; and retired the common units.
	Common units
	Our common units represent limited partner interests in us. The holders of our common units are entitled to participate in our distributions and are entitled to exercise the rights and privileges available to limited partners under our Partnership Agreement. We had 12,253,985 and 12,213,713 common units outstanding as of December 31, 2013 and December 31, 2012, respectively. In February 2014, we completed a public equity offering of 9,200,000 additional common units.
	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. We had 12,213,713 subordinated units issued and outstanding as of December 31, 2013 and December 31, 2012.
	General Partner interests
	Our general partner interest consisted of 534,638 general partner units as of December 31, 2013 and 498,518 general partner units as of December 31, 2012.  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% interest in us. In connection with the Private Placement, our General Partner made a capital contribution in the amount of $0.8 million during the second quarter of 2013 in order to maintain its 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 sale of the Series A Preferred Units (See Note 4). In February 2014, our General Partner purchased an additional 188,582 general partner units in connection with the public equity offering and the vesting of LTIP units (See Note 13).
	Members' Equity of Southcross Energy LLC
	On August 6, 2009, five members of the Southcross Energy LLC's management team purchased, directly or indirectly through Estrella Energy, LP, Class A common units and Class B units along with Charlesbank, for the same value as Charlesbank, ($1.00 per unit). Estrella Energy, LP was partially owned by a non-management third-party, and thus a portion of the time- and performance-based units ("Third-Party Units") owned by Estrella Energy, LP were owned indirectly by the non-management third-party.
	As of December 31, 2011, Southcross Energy LLC's common equity was comprised of 1,415,729 Class A authorized and outstanding common units, of which 217,483 were unvested, and 57,279 authorized and outstanding Class B units, of which 34,367 were unvested. The Class B units have the same distribution and liquidation rights as the Class A common units; however, they do not have voting rights. All Class A common units and Class B units were sold for, and have a par value of, $1.00 per unit.
	Certain of the Class A common units and all of the Class B units contain time- and performance-vesting conditions. Time-vesting units vest ratably over 5 years subject to certain accelerated vesting based primarily on change of control or certain termination causes. Performance-vesting units will vest, if at all, upon Charlesbank attaining certain investment multiples and internal rates of return in connection with a liquidity event. Both the time- and performance vesting units require continued employment through any vesting date. The change in structure and ownership as a result of our IPO did not create a change of control event under the terms of the time- and performance-vesting units.
	On March 20, 2012, Estrella Energy, LP was dissolved and Southcross Energy LLC purchased and retired the Third-Party Units for $15.3 million. Management did not receive any consideration in connection with such repurchase.

PARTNERS_CAPITAL_AND_MEMBERS_E

PARTNERS' CAPITAL AND MEMBERS' EQUITY	12 Months Ended
	Dec. 31, 2013
Partners' Capital Notes [Abstract]	'
PARTNERS' CAPITAL AND MEMBERS' EQUITY	'
	SERIES A CONVERTIBLE PREFERRED UNITS
	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 during the second quarter of 2013 for a cash purchase price of $22.86 per unit. Southcross Energy LLC sold 1,500,000 of these Series A Preferred Units to third parties during the second quarter of 2013.
	Our total capital infusion of $40.0 million, from all sales of Series A Preferred Units and General Partner capital contributions, was used to reduce borrowings under our Credit Facility (See Note 7). The Private Placement of Series A Preferred Units resulted in proceeds to us of $39.2 million. We also received a $0.8 million capital contribution from our General Partner to maintain its 2.0% general partner interest in us.
	Applicable accounting guidance related to the Series A Preferred Units requires that equity instruments with redemption features that are redeemable at the option of the holder be classified outside of permanent equity.  The change of control rights associated with the Series A Preferred Units requires the units to be classified outside of permanent equity.  The Series A Preferred Units have been adjusted to maximum redemption value in accordance with the change of control rights provision of our Partnership Agreement in the event that maximum redemption value exceeds the fair value of the unit at the issuance date. The distributions and adjustments to maximum redemption value associated with the Series A Preferred Units of $1.7 million have been included in the calculation of partners’ capital and earnings per unit for the year ended December 31, 2013. Additionally, none of the identified embedded derivatives relating to the terms of the Series A Preferred Units require bifurcation, as each embedded derivative was determined to be clearly and closely related to the host contract.
	Voting Rights: The Series A Preferred Units are a class of voting equity security that ranks senior to all of our other classes or series of equity securities with respect to distribution rights and rights upon liquidation.  The Series A Preferred Units have voting rights identical to the voting rights of the common units and vote with the common units as a single class, such that each Series A Preferred Unit (including each Series A Preferred Unit issued as an in-kind distribution, discussed below) is entitled to one vote for each common unit into which such Series A Preferred Unit is convertible on each matter with respect to which each common unit is entitled to vote.
	Distribution Rights: Holders of Series A Preferred Units are entitled to quarterly distributions of in-kind Series A Preferred Units for the first four full quarters following the issue date of those units and continuing thereafter until the board of directors of our General Partner determines to begin paying quarterly distributions in cash, and thereafter in cash. The board of directors of our General Partner may not elect to begin paying quarterly distributions on the Series A Preferred Units in cash until we have exercised the Target Leverage Option (pursuant to the Second Amendment) under our Credit Facility. In-kind distributions will be made 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) or, beginning after four full quarters, such higher per unit rate as is paid in respect of our common units. Cash distributions will equal the greater of $0.40 per unit per quarter or the quarterly distribution paid with respect to each common unit. The fair value of an in-kind distribution is calculated as required, based on the common unit price at the quarter end date for the period attributable to the distribution.
	Conversion Rights: Beginning on the later of January 1, 2015 and the date we exercise the Target Leverage Option (pursuant to the Second Amendment), Series A Preferred Units (including Series A Preferred Units issued as in-kind distributions) will be convertible into common units on a one-for-one basis, except that conversion will be prohibited to the extent that it would cause (on a pro forma basis) our estimated quarterly distributions over any of the succeeding four quarters to exceed our total distributable cash flow in that quarter.
	Additionally, on the later of January 1, 2015 and the date we exercise the Target Leverage Option (pursuant to the Second Amendment), we will have the right at any time to convert all or some of the Series A Preferred Units (including Series A Preferred Units issued as in-kind distributions) then outstanding into common units if (i) the daily volume-weighted average trading price of the common units on the national securities exchange on which the common units are listed or admitted to trading for the trailing 30-trading-day period before our notice of conversion is greater than 130% of the unit purchase price for the Series A Preferred Units, (ii) the average daily trading volume of common units on the securities exchange exceeds 40,000 common units for those 30 trading days and (iii) the conversion would not cause (on a pro forma basis) our estimated quarterly distributions over any of the succeeding four quarters to exceed our total distributable cash flow in that quarter.  Further, the Series A Preferred Units will be convertible into common units based on an exchange ratio of 110% of the Series A Preferred Units if a third party acquires majority ownership control of our General Partner or we sell substantially all of our assets, in either case before January 1, 2015.
	PARTNERS' CAPITAL AND MEMBERS' EQUITY
	Shelf Registration Statement and Public Offering
	On November 29, 2013, we filed a Registration Statement on Form S-3 with the U.S. Securities and Exchange Commission (the "SEC") using a "shelf" registration process. Under the shelf registration process, we may over time, in one or more offerings, offer and sell any combination of the securities described in the prospectus, and the selling unitholders may, over time, in one or more offerings, offer and sell common units representing limited partner interests in us. We, together with Southcross Energy Finance Corp., may offer and sell debt securities described in the prospectus. Southcross Energy Finance Corp. may act as co-issuer of the debt securities, and certain direct or indirect subsidiaries of us may guarantee any debt securities offered, if and to the extent identified in the related prospectus supplement. The aggregate initial offering price of all securities sold by us under the prospectus will not exceed $675.0 million.
	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 $148.8 million, before estimated expenses related to the offering of $0.4 million. We plan to use the net proceeds from the offering to fund the recently announced construction of our new pipeline extending into Webb County, Texas and for general partnership purposes, including future permitted acquisitions. Pending such use, we temporarily repaid borrowings under our senior secured revolving credit facility with Wells Fargo, N.A. and a syndicate of lenders (as amended, our "Credit Facility"), which we will redraw to fund the construction of the new pipeline and for other general purposes.
	Partners' Capital
	On November 7, 2012, we completed our IPO. Through a series of transactions, Southcross Energy LLC contributed all of its operating subsidiaries (its net assets on a historical cost basis), excluding certain liabilities and all preferred units, and became the holding company of us. Southcross Energy LLC holds all of the equity interests in our General Partner, as well as all subordinated units and a portion of the common units of us. Subsequent to our IPO, we own Southcross Energy LLCs' operating subsidiaries. At the completion of our IPO, we received proceeds of approximately $168.0 million, net of underwriters' discounts and structuring fees. In connection with the full exercise of the underwriter's over-allotment option, which closed on November 26, 2012, our underwriters purchased 1,350,000 additional common units in us for approximately $25.2 million in proceeds, net of underwriters' and structuring fees; and we used the net proceeds of $25.2 million to reacquire 1,350,000 common units from Southcross Energy LLC; and retired the common units.
	Common units
	Our common units represent limited partner interests in us. The holders of our common units are entitled to participate in our distributions and are entitled to exercise the rights and privileges available to limited partners under our Partnership Agreement. We had 12,253,985 and 12,213,713 common units outstanding as of December 31, 2013 and December 31, 2012, respectively. In February 2014, we completed a public equity offering of 9,200,000 additional common units.
	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. We had 12,213,713 subordinated units issued and outstanding as of December 31, 2013 and December 31, 2012.
	General Partner interests
	Our general partner interest consisted of 534,638 general partner units as of December 31, 2013 and 498,518 general partner units as of December 31, 2012.  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% interest in us. In connection with the Private Placement, our General Partner made a capital contribution in the amount of $0.8 million during the second quarter of 2013 in order to maintain its 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 sale of the Series A Preferred Units (See Note 4). In February 2014, our General Partner purchased an additional 188,582 general partner units in connection with the public equity offering and the vesting of LTIP units (See Note 13).
	Members' Equity of Southcross Energy LLC
	On August 6, 2009, five members of the Southcross Energy LLC's management team purchased, directly or indirectly through Estrella Energy, LP, Class A common units and Class B units along with Charlesbank, for the same value as Charlesbank, ($1.00 per unit). Estrella Energy, LP was partially owned by a non-management third-party, and thus a portion of the time- and performance-based units ("Third-Party Units") owned by Estrella Energy, LP were owned indirectly by the non-management third-party.
	As of December 31, 2011, Southcross Energy LLC's common equity was comprised of 1,415,729 Class A authorized and outstanding common units, of which 217,483 were unvested, and 57,279 authorized and outstanding Class B units, of which 34,367 were unvested. The Class B units have the same distribution and liquidation rights as the Class A common units; however, they do not have voting rights. All Class A common units and Class B units were sold for, and have a par value of, $1.00 per unit.
	Certain of the Class A common units and all of the Class B units contain time- and performance-vesting conditions. Time-vesting units vest ratably over 5 years subject to certain accelerated vesting based primarily on change of control or certain termination causes. Performance-vesting units will vest, if at all, upon Charlesbank attaining certain investment multiples and internal rates of return in connection with a liquidity event. Both the time- and performance vesting units require continued employment through any vesting date. The change in structure and ownership as a result of our IPO did not create a change of control event under the terms of the time- and performance-vesting units.
	On March 20, 2012, Estrella Energy, LP was dissolved and Southcross Energy LLC purchased and retired the Third-Party Units for $15.3 million. Management did not receive any consideration in connection with such repurchase.

SOUTHCROSS_ENERGY_LLC_PREFERRE

SOUTHCROSS ENERGY LLC PREFERRED UNITS	12 Months Ended
	Dec. 31, 2013
Temporary Equity Disclosure [Abstract]	'
SOUTHCROSS ENERGY LLC PREFERRED UNITS	'
	SOUTHCROSS ENERGY LLC PREFERRED UNITS
	In connection with our IPO and through a series of transactions described in Note 11, Southcross Energy LLC contributed all of its operating subsidiaries (its net assets on a historical cost basis), excluding certain liabilities, common units and all preferred units, and became the holding company of us. This note discloses Southcross Energy LLC's preferred units as of November 7, 2012 (our IPO date) and December 31, 2011, as well as the activity associated with the preferred units for the period from January 1, 2012 through our IPO and for the year ended December 31, 2011.
	None of the preferred units (Preferred, Redeemable Preferred and Series B Redeemable Preferred) were conveyed in our IPO, and remain the obligation of Southcross Energy LLC and not us.
	Preferred Units
	As of November 7, 2012 and December 31, 2011, Southcross Energy LLC's cumulative preferred units were comprised of 11,850,374 units with a par value of $10 per unit, which accrued value (in the form of additional preferential rights to receive distributions) at a rate of 10% per annum, compounded quarterly.
	Except in the case of cash distributions made for the purpose of paying federal income taxes, which are made to both preferred and common equity owners in direct proportion to the owners' respective share of taxable income, owners of the preferred equity receive cash distributions before owners of common equity. The cumulative preferred units and their cumulative return are subordinated to all redeemable preferred units and their cumulative return as discussed below. With the exception of cash distributions for federal income tax purposes, the Credit Agreement included certain covenants that restricted Southcross Energy LLC's ability to pay cash dividends to its owners. Southcross Energy LLC adjusts the carrying value of the Preferred Units to reflect the cumulative right to receive distributions on a quarterly basis. As of November 7, 2012, and December 31, 2011, the preferred units' cumulative right to receive future cash distributions was $43.3 million and $31.8 million, respectively, as a result of the cumulative preferred return on such units.
	Redeemable Preferred Units
	As mentioned above, none of the redeemable preferred units were conveyed in our IPO, and they remain the obligation of Southcross Energy LLC. On June 10, 2011, in connection with Southcross Energy LLC entering into the Credit Agreement, Charlesbank and certain of Southcross Energy LLC's existing investors contributed a total of $15.0 million in exchange for 1.5 million Redeemable Preferred Units. The Redeemable Preferred Units have a par value of $10 per unit and accrue value (in the form of an additional preferential right to receive distributions) at a rate of 18% per annum, compounded quarterly. These Redeemable Preferred Units could be redeemed in whole or in part at any time, or would be redeemed by Southcross Energy LLC promptly after the satisfaction of all obligations under the Credit Agreement, to the extent of available funds. Southcross Energy LLC adjusted the carrying value of the Redeemable Preferred Units to reflect the cumulative right to receive distributions on a quarterly basis. As of November 7, 2012 and December 31, 2011, the right of the Redeemable Preferred Units to receive future cash distributions included an additional $3.9 million and $1.6 million, respectively, as a result of the cumulative preferred return on such units.
	Series B Redeemable Preferred Units
	As mentioned above, none of the redeemable preferred units were conveyed in our IPO, and they remain the obligation of Southcross Energy LLC. On March 20, 2012, Charlesbank and certain of Southcross Energy LLC's existing investors contributed $25.3 million and an affiliate of Wells Fargo Securities, LLC contributed $10.0 million to Southcross Energy LLC in exchange for 2.53 million units and 1.0 million units, respectively, of a new, Series B class, of Redeemable Preferred Units ("Series B Units"). On June 26, 2012, Charlesbank and certain of Southcross Energy LLC's existing investors contributed $7.5 million to Southcross Energy LLC in exchange for 0.75 million Series B Units.
	On November 7, 2012 and subsequent to our IPO, the Series B Units were comprised of 3.35 million units. On November 26, 2012 and subsequent to the Over-Allotment Option, Southcross Energy LLC redeemed 2.49 million units. The Series B Units have a par value of $10 per unit, which accrue value (in the form of an additional preferential right to receive distributions) at a rate of 18% per annum, compounded quarterly. The Series B Units could be redeemed by Southcross Energy LLC in whole or in part at any time, or would be redeemed by Southcross Energy LLC promptly after the satisfaction of all its obligations under the Credit Agreement, to the extent of available funds. Southcross Energy LLC adjusts the carrying value of the Series B Units to reflect the cumulative right to receive distributions on a quarterly basis. As of November 7, 2012 and November 26, 2012, the Series B Units' right to receive future cash distributions included $3.8 million and $4.4 million, respectively as a result of the cumulative preferred return.
	Series C Redeemable Preferred Units
	As mentioned above, none of the redeemable preferred units were conveyed in our IPO, and they remain the obligation of Southcross Energy LLC. On June 26, 2012, Charlesbank and certain of Southcross Energy LLC's existing investors and other institutional investors contributed $30.0 million to Southcross Energy LLC in exchange for 3.0 million units of a new, Series C class, of Redeemable Preferred Units ("Series C Units"). As of November 7, 2012, the Series C Units were comprised of 3.0 million units with a par value of $10 per unit, which accrue value (in the form of an additional preferential right to receive distributions) at a rate of 18% per annum, compounded quarterly. The Series C Units and their cumulative preferred return of $1.4 million as of November 7, 2012 were fully redeemed in connection with our IPO (See Note 11).

INCENTIVE_COMPENSATION

INCENTIVE COMPENSATION	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
UNIT BASED COMPENSATION	'
	COMPENSATION
	Unit Based Compensation
	Long-Term Incentive Plan
	On November 7, 2012, and in conjunction with our IPO, we established our 2012 Long-Term Incentive Plan, 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 in either a common unit of us 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 which grants the holder the right to receive an amount equal to all or a portion of the cash distributions made on units during the period the unit remains outstanding.
	The following table summarizes information regarding the LTIP unit activity:
		Units		Weighted-average
				grant date fair value
	Unvested - November 7, 2012	—		$	—
	Granted units	146,000		23.01
	Forfeited units	(1,500	)	23.01
	Vested units	—		—
	Unvested - December 31, 2012	144,500		$	23.01
	Granted units	112,179		21.96
	Forfeited units	(20,700	)	22.09
	Units recaptured for tax withholdings	(13,034	)	23.01
	Vested units	(40,272	)	22.3
	Unvested - December 31, 2013	182,673		$	22.55
	We granted awards under the LTIP, which we have classified as equity awards, with a grant date fair value of approximately $2.5 million for the year ended December 31, 2013. As of December 31, 2013, we had total unamortized compensation expense of approximately $3.6 million related to these units, which we expect to be amortized over the three-year vesting period. As of December 31, 2013, we had 1,527,055 units available for issuance under the LTIP.
	Southcross Energy LLC Phantom Units
	Southcross Energy LLC provided certain key non-officer employees with equity incentive units ("Phantom Units") in Southcross Energy LLC. The Phantom Units vest upon the occurrence of a change in control where more than 50% of the voting power of Southcross Energy LLC changes hands, or upon the occurrence of a liquidity event where, through the sale of some portion of its ownership, the majority owner of Southcross Energy LLC achieves or exceeds a targeted rate of return on its original investment. The changes in structure and ownership as a result of our IPO did not create a change of control event under the vesting terms of the Phantom Units. The number of Phantom Units earned and eligible for vesting increases over a period of years or through the achievement of certain rates of return by the majority owner of the Southcross Energy LLC or a combination thereof. As of December 31, 2013 and 2012, no fair value was attributable to the Phantom Units. No compensation expense associated with these units was recorded during the year ended December 31, 2013 and 2012. As of December 31, 2013 and 2012 the number of authorized and issued Phantom Units was 10,832.
	Southcross Energy LLC Executive Equity Equivalent Units
	On April 1, 2012, Southcross Energy LLC granted 15,000 equity equivalent units ("EEUs") to a member of management. Each individual EEU is equivalent in economic value to one Class A Common Unit of Southcross Energy LLC on a fully diluted basis. The EEUs have time and performance vesting over a three year term. Compensation expense for the EEUs recognized in general and administrative expenses on the statements of operation was $0.6 million and $0.4 million for the years ended December 31, 2013 and 2012, respectively.
	Unit Based Compensation Expense
	The following table summarizes information regarding recognized compensation expense, which is included in general and administrative expense on our consolidated statements of operations (in thousands):
		Year Ended December 31,
		2013			2012		2011
	Unit-based compensation	$	2,186		$	630	$	—
	Employee Savings Plan
	We have employee savings plans under Sections 401(a) and 401(k) of the Internal Revenue Code ("IRC") whereby employees of our General Partner may contribute a portion of their base compensation to the employee savings plan, subject to limits under the IRC. We provide a matching contribution each payroll period equal to 100% of the employee's contribution up to the lesser of 6% of the employee's pay 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 consolidated statements of operations (in thousands):
		Year Ended December 31,
		2013			2012		2011
	Matching contributions expensed for employee savings plan	$	628		$	512	$	417

REVENUES

REVENUES	12 Months Ended
	Dec. 31, 2013
Revenues [Abstract]	'
REVENUES	'
	REVENUES
	We had revenues consisting of the following categories (in thousands):
		Year ended December 31,
		2013		2012		2011
	Sales of natural gas	$	405,206	$	325,421	$	385,513
	Sales of NGLs and condensate	169,523		124,139		106,487
	Transportation, gathering and processing fees	59,392		46,113		30,102
	Other	601		456		1,047
	Total revenues	$	634,722	$	496,129	$	523,149

CONCENTRATION_OF_CREDIT_RISK_A

CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE	12 Months Ended
	Dec. 31, 2013
Risks and Uncertainties [Abstract]	'
CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE	'
	CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE
	Our primary markets are in South Texas, Alabama and Mississippi. We have a concentration of revenues and trade accounts receivables 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 similarly affected by changes in economic, regulatory or other factors. We analyze the customers' historical financial and operational information prior to extending credit.
	Our top ten customers for the years ended December 31, 2013, 2012 and 2011 represent the following percentages of consolidated revenue:
		Year Ended December 31,
		2013		2012		2011
	Top 10 customers	59.7	%	65.5	%	73.1	%
	The percentage of total consolidated revenue for each customer that exceeded 10% of total revenues for the years ended December 31, 2013, 2012 and 2011 was as follows:
		Year Ended December 31,
		2013		2012		2011
	Sherwin Alumina Company	11.7	%	11	%	15.5	%
	Formosa Hydrocarbons Co., Inc.	(a),(b)		24.3	%	20.8	%
	(a) Information is not provided for periods for which the customer or producer was less than 10% of our consolidated revenue.
	(b) Our contract with Formosa terminated on June 1, 2013.
	During the years ended December 31, 2013, 2012 and 2011 we experienced no significant non-payment for services. At December 31, 2013 and 2012, we have recorded no allowance for uncollectible accounts receivable.

SUBSEQUENT_EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
SUBSEQUENT EVENTS	'
	SUBSEQUENT EVENTS
	Partnership Distribution
	On January 24, 2014, we declared a cash distribution of $0.40 per common unit and subordinated unit, including units equivalent to our General Partner’s 2.0% interest in us, which was paid on February 14, 2013 to unitholders of record on February 5, 2013.  Also on January 24, 2014, we declared a Series A Preferred Unit distribution of $0.40 per unit, which was paid in-kind on February 14, 2013 to unitholders of record on February 5, 2013, and our General Partner will receive a number of general partner units to maintain our General Partner’s 2.0% interest in us.
	Third Amendment to Credit Facility
	On January 29, 2014, we entered into the Third Amendment to our Credit Facility (see Note 7).
	Public Offering of Common Units
	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 $148.8 million, before estimated expenses related to the offering of $0.4 million (see Note 11).

SUPPLEMENTAL_CASH_FLOW_INFORMA

SUPPLEMENTAL CASH FLOW INFORMATION SUPPLEMENTAL CASH FLOW INFORMATION	12 Months Ended
	Dec. 31, 2013
Supplemental Cash Flow Elements [Abstract]	'
SUPPLEMENTAL CASH FLOW INFORMATION	'
	SUPPLEMENTAL CASH FLOW INFORMATION
		Year ended December 31,
		2013		2012		2011
	Supplemental Disclosures:
	Cash paid for interest, net of amounts capitalized	$	13,043	$	10,552	$	7,994
	Cash paid for taxes, net of refunds received	95		315		272
	Supplemental schedule of non-cash investing and financing activities:
	Accounts payable related to capital expenditures	4,946		40,707		10,862
	Change in value recognized in other comprehensive income	148		745		—
	Capital lease obligation	1,396		—		—
	Accrued distribution equivalent rights (DERs) on the LTIP units	279		—		—
	Other	$	704	$	—	$	—

SUPPLEMENTAL_SELECTED_QUARTERL

SUPPLEMENTAL SELECTED QUARTERLY FINANCIAL INFORMATION (UNAUDITED) SUPPLEMENTAL SELECTED QUARTERLY FINANCIAL INFORMATION (UNAUDITED)	12 Months Ended
	Dec. 31, 2013
Condensed Financial Information of Parent Company Only Disclosure [Abstract]	'
SUPPLEMENTAL SELECTED QUARTERLY FINANCIAL INFORMATION (UNAUDITED)	'
	SUPPLEMENTAL SELECTED QUARTERLY FINANCIAL INFORMATION (UNAUDITED)
	The following presents a summary of selected quarterly financial information (in thousands, except per unit data):
		Quarters ended
	2013	March 31			June 30			September 30			December 31					Total
	Revenues	$	144,250		$	154,703		$	160,629		$	175,140				$	634,722
	Gross operating margin	18,863			21,296			25,213			28,174					93,546
	(Loss) income from operations	(4,317		)	(2,831		)	(357		)	4,485					(3,020		)
	Net (loss) income	(6,382		)	(6,192		)	(4,069		)	673					(15,970		)
	General partner's interest in net loss	(128		)	(124		)	(81		)	14					(319		)
	Limited partners' interest in net loss	(6,254		)	(11,294		)	(17		)	244					(17,321		)
	Cash distribution attributable per quarter	9,973			9,986			9,987			13,755					43,701
	Basic net (loss) income per common unit	(0.26		)	(0.65		)	0.19			0.01
	Diluted net (loss) income per common unit	(0.26		)	(0.65		)	(0.14		)	0.01
	Basic and diluted net loss per subordinated unit	(0.26		)	(0.27		)	(0.19		)	0.01
		Quarters ended									Periods ended
	2012	March 31			June 30			September 30			October 1, 2012-			November 7, 2012-				Total
											November 6, 2012(1)			December 31, 2012(1)(2)
	Revenues	$	120,618		$	105,701		$	118,150		$	55,613		$	96,047			$	496,129
	Gross operating margin	21,416			18,698			15,078			6,741			9,707				71,640
	Income (loss) from operations	8,120			3,442			(2,686		)	(1,589		)	(3,998		)		3,289
	Net income (loss)	$	6,236		$	1,939		$	(4,041	)	$	(4,394	)	(4,228		)		(4,488		)
	Cash distribution attributable per quarter													5,982				5,982
	General partner's interest in net loss													(85		)		(85		)
	Limited partners' interest in net loss													(4,143		)		(4,143		)
	General partners' net loss per unit—basic and diluted													(0.17		)		(0.17		)
	Limited partners' net loss per unit—basic and diluted													(0.17		)		(0.17		)
	_______________________________________________________________________________
	-1	See Note 1 for a description of decreases in statements of operations during this period.
	-2	Represents results of Southcross Energy Partners, L.P. subsequent to our IPO on November 7, 2012.

BASIS_OF_PRESENTATION_Policies

BASIS OF PRESENTATION (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Basis of Presentation	'
	Basis of Presentation
	The accompanying consolidated financial statements and related notes present the consolidated balance sheets as of December 31, 2013 and 2012 and the consolidated statements of operations, consolidated statements of comprehensive income (loss), consolidated statements of cash flows and changes in partners' capital and members' equity for the years ended December 31, 2013, 2012 and 2011. As a result of our IPO, there was no change in the accounting basis of the contributed net assets of Southcross Energy LLC. Information included in these financial statements and related notes are presented as if we and Southcross Energy LLC were the same entity, except with respect to associated changes in capitalization as described in Note 11.
	The accompanying consolidated financial statements were prepared in accordance with accounting principles generally accepted in the U.S. ("GAAP") and in accordance with the rules and regulations of the U.S. Securities and Exchange Commission ("SEC"). Our consolidated financial statements include the accounts of Southcross and its 100% owned subsidiaries. We eliminate all intercompany balances and transactions in preparing consolidated financial statements.
Principles of Consolidation	'
	Principles of Consolidation
	We consolidate entities when we have the ability to control or direct the operating and financial decisions of the entity or when we have a significant interest in the entity that gives us the ability to direct the activities that are significant to that entity. The determination of our ability to control, direct or exert significant influence over an entity involves the use of judgment. We do not have ownership in any variable interest entities.
Use of Estimates	'
	Use of Estimates
	The preparation of the consolidated financial statements in conformity with GAAP requires management to make various estimates and assumptions that may affect the amounts of assets and liabilities, disclosures of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the period. Actual results may differ from those estimates.
Cash and Cash Equivalents	'
	Cash and Cash Equivalents
	We consider all short term investments with an original maturity of three months or less to be cash equivalents. At December 31, 2013 and 2012, except for amounts held in bank accounts to cover current payables, all of our cash equivalents were invested in short-term money market instruments.
Allowance for Doubtful Accounts	'
	Allowance for Doubtful Accounts
	In evaluating the collectability of our accounts receivable, we perform ongoing credit evaluations of our customers and adjust payment terms based upon payment history and each customer's current creditworthiness, as determined by our review of such customer's credit information. We extend credit on an unsecured basis to many of our customers. At December 31, 2013 and 2012, we have recorded no allowance for uncollectible accounts receivable.
Debt Issuance Costs	'
	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 consolidated balance sheets.
Long-Lived Assets	'
	Long-Lived Assets
	Our property, plant and equipment is recorded at its original cost of construction or, upon acquisition, at fair value of the assets acquired. For assets we construct, we capitalize direct costs, such as labor and materials, and indirect costs, such as overhead and the cost of financing construction. Costs associated with obtaining rights of way agreements and easements to facilitate the building and maintenance of new pipelines are capitalized and depreciated over the life of the associated pipeline. We capitalize major units of property replacements or improvements and expense minor items. We use the straight-line method to depreciate property, plant and equipment over the estimated useful lives of the assets. We depreciate leasehold improvements and capital lease assets over the shorter of the life of the asset or the life of the lease. Maintenance and repairs are charged directly to expense.
	Our intangible assets consist of acquired long-term supply and gas gathering contracts. We amortize these contracts on a straight-line basis over the 30-year expected useful lives of the contracts.
	Impairment of Long-Lived Assets
	We evaluate our long-lived assets, which include finite-lived intangible assets, for impairment when events or circumstances indicate that their carrying values may not be recoverable. These events include, but are not limited to, market declines that are believed to be other than temporary, changes in the manner in which we intend to use a long-lived asset, decisions to sell an asset and adverse changes in the legal or business environment such as adverse actions by regulators. If an event occurs, we evaluate the recoverability of our carrying value based on the long-lived asset's ability to generate future cash flows on an undiscounted basis. If the undiscounted cash flows are not sufficient to recover the long-lived asset's carrying value, or if we decide to sell a long-lived asset or group of assets, we adjust the carrying values of the asset downward, if necessary, to their estimated fair value. Our fair value estimates are generally based on assumptions market participants would use, including market data obtained through the sales process or an analysis of expected discounted cash flows. At December 31, 2013, 2012 and 2011, we have not recorded an impairment of long-lived assets.
Capitalization of Interest Cost	'
	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.
Asset Retirement Obligations	'
	Asset Retirement Obligations
	We evaluate whether any future asset retirement obligations ("AROs") exist and estimate the costs for such AROs for certain future events. An ARO will be recorded in the periods where we can reasonably determine the settlement dates or the period in which the expense is incurred and an estimated cost of the retirement obligation. Generally we do not have the intention of discontinuing the use of any significant assets or have a legal obligation to do so. Therefore, in these situations we do not have sufficient information to reasonably estimate any future AROs. However, during the year ended December 31, 2013, an asset retirement obligation of $0.5 million related to the discontinued use of an asset was recorded in operations and maintenance expense. This ARO is substantially complete and we do not expect significant additional costs. No AROs were recorded for the years ended December 31, 2012 or 2011.
Environmental Costs and Other Contingencies	'
	Environmental Costs and Other Contingencies
	We recognize liabilities for environmental and other contingencies when we have an exposure that indicates it is both probable that a liability has been incurred and the amount of loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue a liability for that amount. Where the most likely outcome cannot be estimated, a range of potential losses is established and no specific amount in that range is more likely than any other, the low end of the range is accrued. No amounts were recorded as of December 31, 2013 and 2012.
Revenue Recognition	'
	Revenue Recognition
	Using the revenue recognition criteria of persuasive evidence of an exchange arrangement exists, delivery has occurred or services have been rendered and the price is fixed or determinable, we record natural gas and NGL revenue in the period when the physical product is delivered to the customer and in an amount based on the pricing terms of an executed contract. Our transportation, compression, processing, fractionation and other revenue is recognized in the period when the service is provided and includes our fee-based service revenue. In addition, collectability is evaluated on a customer-by-customer basis. New and existing customers are subject to a credit review process, which evaluates the customers' financial position and their ability to pay.
	Our sale and purchase arrangements are primarily accounted for on a gross basis in the statements of operations. These transactions are contractual arrangements that establish the terms of the purchase of natural gas or NGLs at a specified location and the sale of natural gas or NGLs at a different location on the same or on another specified date. These transactions require physical delivery and transfer of the risk and reward of ownership are evidenced by title transfer, assumption of environmental risk, transportation scheduling, credit risk and counterparty nonperformance risk.
	We derive revenue in our business from the following types of arrangements:
	•	Fixed-Fee.  We receive a fixed-fee per unit of natural gas volume that we gather at the wellhead, process, treat, compress and/or transport for our customers, or we receive a fixed-fee per unit of NGL volume that we fractionate. Some of our arrangements also provide for a fixed-fee for guaranteed transportation capacity on our systems.
	•	Fixed-Spread.  Under these arrangements, we purchase natural gas and NGLs from producers or suppliers at receipt points on our systems at an index price plus or minus a fixed price differential and sell these volumes of natural gas and NGLs at delivery points off our systems at the same index price, plus or minus a fixed price differential. By entering into such back-to-back purchases and sales, we are able to mitigate our risk associated with changes in the general commodity price levels of natural gas and NGLs. We remain subject to variations in our fixed-spreads to the extent we are unable to precisely match volumes purchased and sold in a given time period or are unable to secure the supply or to produce or market the necessary volume of products at our anticipated differentials to the index price.
	•	Commodity-Sensitive.  In exchange for our processing services, we may remit to a customer a percentage of the proceeds from our sales, or a percentage of the physical volume, of residue natural gas and/or NGLs that result from our natural gas processing, or we may purchase NGLs from customers at set fixed NGL recoveries and retain the balance of the proceeds or physical commodity for our own account. These arrangements are generally combined with fixed-fee and fixed-spread arrangements for processing services and, therefore, represent only a portion of a processing contract's value. The revenues we receive from these arrangements directly correlate with fluctuating general commodity price levels of natural gas and NGLs and the volume of NGLs recovered relative to the fixed recovery obligations.
	Lon
Fair Value of Financial Instruments	'
	Fair Value of Financial Instruments
	Accounting guidance requires the disclosure of the fair value of all financial instruments that are not otherwise recorded at fair value in the financial statements. At December 31, 2013 and 2012, financial instruments recorded at contractual amounts that approximate fair value include certain funds on deposit, accounts receivable, other receivables, and accounts payable and accrued liabilities. The fair values of such items are not materially sensitive to shifts in market interest rates because of the short term to maturity of these instruments (See Note 5).
	The fair value of the debt funded through our Credit Facility approximates its carrying amount as of December 31, 2013 and 2012 due primarily to the variable nature of the interest rate of the instrument. The fair value of the debt is considered a Level 2 fair value measurement (See Note 5).
Derivative Instruments	'
	Derivative Instruments
	In our normal course of business, we enter into month-ahead swap contracts in order to hedge economically our exposure to certain intra-month natural gas index pricing risk. We manage our interest rate risk through interest rate swaps.
	Derivative financial instruments are recorded in the consolidated balance sheets at fair value, except for derivative contracts that we qualify for and for which we have elected the normal purchase or normal sale exceptions, which are not reflected in the consolidated balance sheets or statements of operations prior to accrual of the settlement. We present our derivative assets and liabilities on a net basis.
	If certain criteria are met, a derivative financial instrument may be designated as a fair value hedge or cash flow hedge. In March 2012, we entered into an interest rate swap to reduce the risks with respect to the variability of the interest rates under our Credit Facility. With the exception of these interest rate swaps, we did not have any other derivative financial instruments designated as fair value or cash flow hedges for accounting purposes during the years ended December 31, 2013, 2012 and 2011.
	The changes in fair value of cash flow hedges are deferred in accumulated other comprehensive loss, net of tax, to the extent the contracts are, or have been, effective as hedges, until the forecasted transactions impact earnings. We record the ineffective portion of changes in fair value of cash flow hedges immediately into earnings.
	On an ongoing basis, a derivative instrument designated as a cash flow hedge must be highly effective in offsetting changes in cash flows of the hedged item. If it is determined that the derivative instrument is not highly effective as a hedge, hedge accounting will be discontinued prospectively. Changes in fair value of the associated hedging instrument are then recognized immediately in earnings for the remainder of the contract term unless a new hedging relationship is designated. The assessment of effectiveness excludes counterparty default risk and our own non-performance risk. The effect of these valuation adjustments was immaterial for the years ended December 31, 2013 and 2012, respectively.
	Derivative financial instruments designated as cash flow hedges must have a high correlation between price movements in the derivative and the hedged item. If and when an acceptable level of correlation no longer exists, hedge accounting ceases and changes in fair value are recognized in our statements of operations. If it becomes probable that a forecasted transaction will not occur, we immediately recognize the related deferred gains or losses in our statements of operations. Changes in fair value of the associated hedging instrument are then recognized immediately in earnings for the remainder of the contract term unless a new hedging relationship is designated.
	The interest rate swap is designated as a cash flow hedge for accounting purposes and, thus, to the extent the cash flow hedge is effective, unrealized gains and losses are recorded to accumulated other comprehensive income (loss) and recognized in interest expense as the underlying hedged transactions (interest payments) are recorded. Any hedge ineffectiveness is recognized in interest expense immediately. We did not have any hedge ineffectiveness during the years ended December 31, 2013 and 2012. We have elected to present our commodity swaps net in the balance sheet. We did not have any cash collateral received or paid on our commodity swaps as of December 31, 2013.
	For our derivative financial instruments that have not been designated as cash flow hedges for accounting purposes, changes in such instruments' fair values are recognized currently in earnings. We do not hold or issue financial instruments or derivative financial instruments for trading purposes.
Unit-Based Compensation	'
	Unit-Based Compensation
	Unit-based awards which settle in common units are classified as equity and are recognized in the financial statements over the vesting period at their grant date fair value. Unit-based awards which settle in cash are classified as liabilities and remeasured at every balance sheet date through settlement, such that the vested portion of the liability is adjusted to reflect its revised fair value through compensation expense. Currently, all awards granted under the long-term incentive plan will be settled in common units. Compensation expense associated with unit-based awards, adjusted for forfeitures, is recognized evenly from the date of the grant over the vesting period within general and administrative expenses on our consolidated statements of operations.
Income Taxes	'
	Income Taxes
	No provision for federal or state income taxes is included in our statements of operations as such income is taxable directly to our partners. Each partner is responsible for its share of federal and state income tax. Net earnings for financial statement purposes may differ significantly from taxable income reportable to each partner as a result of differences between the tax basis and financial reporting basis of assets and liabilities.
	We are responsible for our portion of the Texas margin tax that is included in Southcross Energy LLC's consolidated Texas franchise tax return. Our current tax liability will be assessed based on the gross revenue apportioned to Texas. The margin tax qualifies as an income tax under GAAP, which requires us to recognize the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis.
Uncertain Tax Positions	'
	Uncertain Tax Positions
	We evaluate the uncertainty in tax positions taken or expected to be taken in the course of preparing our consolidated financial statements to determine whether the tax positions are more likely than not of being sustained by the applicable tax authority. Tax positions deemed not to meet the more likely than not threshold would be recorded as a tax benefit or expense in the current year.
Earnings per Unit	'
	Earnings per Unit
	Net income (loss) per unit is calculated under the two-class method of computing earnings per unit when participating or multiple classes of securities exist. Under this method, undistributed earnings or losses for a period are allocated based on the contractual rights of each security to share in those earnings as if all of the earnings for the period had been distributed.
	Basic net income (loss) per unit excludes dilution and is computed by dividing net income (loss) attributable to limited partner common units by the weighted average number of limited partner common units outstanding during the period. Paid-in kind distributions and valuation adjustments to maximum redemption value of the Series A convertible preferred units are excluded from income available to common units in the calculation of basic earnings per unit. Dilutive net income (loss) per unit reflects potential dilution from the potential issuance of limited partner common units. Dilutive net income (loss) per unit is calculated using the treasury stock method. It is computed by dividing net income (loss) attributable to limited partner common units by the weighted average number of limited partner common units outstanding during the period increased by the number of additional limited partner common units that would have been outstanding if the dilutive potential limited partner common units had been issued.
New Accounting Pronouncements	'
	New Accounting Pronouncements
	Accounting standard-setting organizations frequently issue new or revised accounting rules. We regularly review all new pronouncements to determine their impact, if any, on our financial statements.
	In January 2013, the FASB issued an accounting standards update on “Disclosures About Offsetting Assets and Liabilities.” This update requires enhanced disclosures regarding the effect or potential effect of netting arrangements on our financial position by improving information about financial instruments and derivative instruments that are either offset in the balance sheet or are subject to an enforceable master netting arrangement or similar agreement, irrespective of whether they are offset. The disclosures are required to be adopted retroactively. We adopted this standard effective January 1, 2013, which did not have a material impact on our financial statements.
	In February 2013, the FASB issued an accounting standards update on "Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income." This update requires that we report reclassifications out of accumulated other comprehensive income and their effect on net income by component or financial statement line effective for our quarterly filing for the three months ended March 31, 2013. We adopted this standard effective January 1, 2013, which did not have a material impact on our financial statements.

BASIS_OF_PRESENTATION_BASIS_OF

BASIS OF PRESENTATION BASIS OF PRESENTATIONS (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Schedule of Interest Costs Incurred	'
	e incurred the following interest costs (in thousands):
		Year Ended December 31,
		2013			2012			2011
	Total interest costs	$	14,047		$	12,035		$	7,157
	Capitalized interest included in property, plant and equipment, net	(1,457		)	(6,268		)	(1,809		)
	Interest expense	$	12,590		$	5,767		$	5,348
Schedule of Debt Issuance Costs	'
	Changes in deferred financing costs are as follows (in thousands):
		Year Ended December 31,
		2013			2012
	Deferred financing costs, January 1	$	4,385		$	2,154
	Capitalization of deferred financing costs (1)	2,139			5,178
	Less:
	Write off of deferred financing costs (1)(2)	—			1,764
	Amortization of deferred financing costs	1,287			1,183
	Deferred financing costs, December 31	$	5,237		$	4,385
	___________________________________________________________________________
	(1) See Note 7.
	(2) Amounts are considered a portion of the net carrying value of the related debt and are expensed when accelerated as a component of a debt extinguishment or modifications accounted for as an extinguishment.

ACQUISITIONS_Tables

ACQUISITIONS (Tables)	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Schedule of reconciliation of the fair values of the assets acquired and liabilities assumed related to the EAI purchase price	'
	The reconciliation of the fair value of the assets acquired and liabilities assumed related to the EAI purchase price was as follows (in thousands):
	Purchase Price—Cash	$	21,777
	Current assets	3,374
	Property, plant, and equipment	19,300
	Intangible assets	1,700
	Total assets acquired	24,374
	Current liabilities assumed	2,597
	Net identifiable assets acquired	$	21,777
Schedule of unaudited pro forma financial information Predecessor includes adjustments for income from operations, including depreciation and amortization	'
	The following unaudited pro forma financial information of our year ended December 31, 2011 assumes that the EAI acquisition occurred on January 1, 2010 and includes adjustments for income from operations, including depreciation and amortization, as well as the effects of financing the acquisition (in thousands, except unit information):
		Year Ended
		December 31, 2011
		Southcross			Combined
	Total revenue	$	523,149		$	548,152
	Net income	7,539			7,789
	Net loss attributable to common unitholders	(8,145		)	(7,895		)
	Net loss per unit—(basic and diluted)	(6.79		)	(6.59		)

EARNINGS_PER_LIMITED_PARTNER_U1

EARNINGS PER LIMITED PARTNER UNIT AND DISTRIBUTIONS (Tables)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Schedule of reconciliation of net loss attributable to limited partners and limited partner units used in basic and diluted earnings per unit calculations	'
	The following is a reconciliation of net loss attributable to limited partners and the limited partner units used in the basic and diluted earnings per unit calculations for the years ended December 31, 2013 and 2012 (in thousands, except per unit data):
	Allocation of Net loss
		Year ended				Year ended
		December 31, 2013				December 31, 2012
	Net loss	$	(15,970	)		$	(4,488	)
	Series A Preferred Unit in-kind distribution and fair value adjustment	(1,670		)		—
	Net loss from January 1, 2012 through November 6, 2012	—				260
	Net loss attributable to partners	(17,640		)		(4,228		)
	General partner's interest (1)	(319		)		(85		)
	Limited partners' interest (1)
	Common	(8,683		)		(2,072		)
	Subordinated	(8,638		)		(2,071		)
	____________________________________________________________________________
	(1) General Partner's and Limited Partner's interest are calculated based on the allocation of net losses for the period, net of the allocation of general partner unit in-kind distributions, Series A Preferred Unit in-kind distributions and Series A Preferred Unit fair value adjustments.
	Common Units
		Year ended				Year ended
		December 31, 2013				December 31, 2012
	Interest in net loss	$	(8,683	)		$	(2,072	)
	Effect of dilutive units - numerator (1)	—				—
	Dilutive interest in net loss	$	(8,683	)		$	(2,072	)
	Weighted-average units - basic	12,224,997				12,213,713
	Effect of dilutive units - denominator (1)	—				—
	Weighted-average units - dilutive	12,224,997				12,213,713
	Basic and diluted net loss per common unit	$	(0.71	)		$	(0.17	)
	Subordinated Units
		Year ended				Year ended
		December 31, 2013				December 31, 2012
	Interest in net loss	$	(8,638	)		$	(2,071	)
	Effect of dilutive units - numerator (1)	—				—
	Dilutive interest in net loss	$	(8,638	)		$	(2,071	)
	Weighted-average units - basic	12,213,713				12,213,713
	Effect of dilutive units - denominator (1)	—				—
	Weighted-average units - dilutive	12,213,713				12,213,713
	Basic and diluted net loss per subordinated unit	$	(0.71	)		$	(0.17	)
	____________________________________________________________________________
	(1)Diluted net income per limited partner unit reflects the potential dilution that could occur if securities or agreements to issue common units, such as the conversion of Series A Preferred Units into common units or the awards under the long-term incentive plan, were exercised, settled or converted into common units. When it is determined that potential common units should be included in the diluted net income per limited partner unit calculation, the impact is reflected by applying the treasury stock method. Because we had a net loss for the year ended December 31, 2013 and 2012, 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. The weighted average units that were not included in the computation of diluted per unit amounts were 10,092 and 144,500 unvested awards granted under our long-term incentive plan for the year ended December 31, 2013 and 2012, respectively, and 1,233,117 Series A Preferred Units for the year ended December 31, 2013.
Distributions Made to Limited Partners and General Partner	'
	The following table represents our distribution declared for the quarter ended December 31, 2013 and distributions paid for the previous periods (in thousands, except per unit data):
												Distributions
			Attributable to the		Per Unit							Limited Partners
	Payment Date		Quarter Ended		Distribution							Common				Subordinated			General Partner			Total
	2013
	February 14, 2014		December 31, 2013		$	0.4						$	8,581			$	4,885		$	289		$	13,755
	November 14, 2013		September 30, 2013		0.4							4,888				4,885			214			9,987
	August 14, 2013		June 30, 2013		0.35				(1	)		—				—			10			10
	August 14, 2013		June 30, 2013		0.2				(2	)		—				—			1			1
	August 14, 2013		June 30, 2013		0.4							4,890				4,886			199			9,975
	May 15, 2013		March 31, 2013		0.4							4,888				4,886			199			9,973
	2012
	14-Feb-13		31-Dec-12		0.24				(3	)		2,931				2,931			120			5,982
	____________________________________________________________________________
	(1) Per unit distribution of $0.35 corresponds to the minimum quarterly distribution of $0.40 per unit, or $1.60 on an annualized basis, pro-rated for the portion of the quarter following the issuance of 29,925 general partner units on April 12, 2013.
	(2) Per unit distribution of $0.20 corresponds to the minimum quarterly distribution of $0.40 per unit, or $1.60 on an annualized basis, pro-rated for the portion of the quarter following the issuance of 5,075 general partner units on May 15, 2013.
	(3) Per unit distribution of $0.24 corresponds to the minimum quarterly distribution of $0.40 per unit, or $1.60 on an annualized basis, pro-rated for the portion of the quarter following the closing of our IPO on November 7, 2012.
Schedule of Paid In-Kind Distributions	'
	The following table represents the paid in-kind (“PIK”) distribution earned for the quarter ended December 31, 2013 and PIK distributions for the previous periods (in thousands, except per unit and in-kind distribution units):
	Payment Date		Attributable to the Quarter Ended		Per Unit Distribution						In-Kind Series A			In-Kind				In-Kind		In-Kind General Partner Distribution Value(3)
											Preferred Unit			Series A				Unit
											Distributions			Preferred				Distribution
											to Series A			Distributions				to General
											Preferred			Fair Value(3)				Partner
											Holders
	2013
	February 14, 2014		December 31, 2013		$	0.4					30,971			$	558			632		$	11
	November 14, 2013		September 30, 2013		0.4						30,439			511				621		10
	August 14, 2013		June 30, 2013		0.35				-1		22,276			512				454		10
	August 14, 2013		June 30, 2013		0.2				-2		2,199			51				45		1
	____________________________________________________________________________
	(1) Per unit distribution of $0.35 corresponds to the minimum quarterly distribution of $0.40 per unit, or $1.60 on an annualized basis, pro-rated for the portion of the quarter following the issuance of 1,466,325 Series A Preferred Units and 29,925 general partner units on April 12, 2013.
	(2) Per unit distribution of $0.20 corresponds to the minimum quarterly distribution of $0.40 per unit, or $1.60 on an annualized basis, pro-rated for the portion of the quarter following the issuance of 248,675 Series A Preferred Units and 5,075 general partner units on May 15, 2013.
	(3) 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)	12 Months Ended
	Dec. 31, 2013
Derivatives	'
Schedule of the fair value of the interest rate cap and interest rate swap liabilities	'
	he fair value of the interest rate swap liabilities were as follows (in thousands):
		Significant Other Observable Inputs (Level 2)
		Fair value measurement as of
		December 31, 2013			December 31, 2012
	Interest rate swap liability	$	263		$	638
Schedule of cash flow hedges effect on partners' capital and comprehensive income (loss)	'
	The effect of the interest rate swap designated as a cash flow hedge in our statements of changes in partners’ capital and members’ equity and comprehensive income/(loss) were as follows (in thousands):
		Year ended December 31,
		2013			2012			2011
	Change in value recognized in other comprehensive loss - effective portion	$	(148	)	$	(745	)	$	—
	Loss reclassified from accumulated other comprehensive loss to interest expense	$	415		$	268		$	—
Schedule of offsetting assets and liabilities	'
	The effect of offsetting in our balance sheet was as follows (in thousands):
			Other Current Assets		Other Current Liabilities
	Commodity Swaps
	Gross Amounts of Recognized Assets / (Liabilities)		140		(20	)
	Gross Amounts Offset in the Balance Sheet		(20	)	20
	Net Amount		120		—
Interest rate cap contract	'
Derivatives	'
Schedule of amounts recognized in the statement of operations	'
	The amounts recognized in interest expense associated with derivatives that are not designated as hedging instruments were as follows (in thousands):
		Year ended December 31,
		2013			2012			2011
	Unrealized loss on interest rate cap	$	—		$	141		$	21
	Realized loss on interest rate cap	$	108		$	82		$	147
Commodity Swaps	'
Derivatives	'
Schedule of amounts recognized in the statement of operations	'
	The realized and unrealized gain/(loss) on these derivatives, recognized in revenues in our statements of operations were as follows (in thousands):
		Year ended December 31,
		2013			2012			2011
	Realized gain/(loss) on derivatives	$	(659	)	$	(12	)	$	179
	Unrealized gain/(loss) on derivatives	120			—			—

LONGLIVED_ASSETS_Tables

LONG-LIVED ASSETS (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Schedule of property, plant and equipment	'
	Property, plant and equipment consist of the following (in thousands):
		Estimated	As of December 31,
		Useful Life	2013			2012
	Pipelines	30	$	344,721		$	250,177
	Gas processing, treating and other plants	15	254,133			221,594
	Compressors	7	20,030			19,241
	Rights of way and easements	15	20,729			20,729
	Furniture, fixtures and equipment	5	3,347			3,087
	Capital lease vehicles	5-Mar	1,396			—
	Total property, plant and equipment		644,356			514,828
	Accumulated depreciation and amortization		(79,908		)	(46,466		)
	Total		564,448			468,362
	Construction in progress		6,039			77,011
	Land and other		5,308			5,230
	Property, plant and equipment, net		$	575,795		$	550,603

LONGTERM_DEBT_Tables

LONG-TERM DEBT (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Schedule of long-term debt	'
	Our long-term debt consisted of the following (in thousands):
		As of December 31,
		2013		2012
	Credit Facility, due November 2017	$	267,300	$	191,000
	Total	267,300		191,000
	Less:
	Current maturities of long-term debt	—		—
	Total long-term debt	$	267,300	$	191,000
Schedule of maximum adjusted consolidated total leverage ratio	'
	The Second Amendment provides that until we satisfy the Target Leverage Ratio, we are allowed to calculate an adjusted consolidated total leverage ratio, which allows for the netting of total funded indebtedness with amounts on deposit in the Collateral Account, and we may not permit our adjusted consolidated total leverage ratio to exceed the ratio set forth below for the corresponding period (as provided in our Credit Facility):
		Maximum Adjusted Consolidated Total Leverage Ratio
	September 30, 2013	7.25 to 1.00
	December 31, 2013	6.75 to 1.00
	March 31, 2014	6.25 to 1.00
	June 30, 2014	5.25 to 1.00
	September 30, 2014	5.00 to 1.00
	December 31, 2014	4.75 to 1.00
	March 31, 2015 and thereafter	4.50 to 1.00
Schedule of maximum consolidated total leverage ratio	'
	Upon satisfying the Target Leverage Ratio, beginning with the quarter ended September 30, 2013, the Second Amendment provides that we will not permit our Maximum Consolidated Total Leverage Ratio to exceed the ratio set forth below for the corresponding period (as provided in our Credit Facility):
		Maximum Consolidated
		Total Leverage Ratio
	September 30, 2013	4.75 to 1.00
	December 31, 2013 and thereafter	4.50 to 1.00

COMMITMENTS_AND_CONTINGENT_LIA1

COMMITMENTS AND CONTINGENT LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of future minimum annual rental commitments under capital and operating leases	'
	Future minimum annual rental commitments under our capital and operating leases at December 31, 2013 were as follows (in thousands):
	Years Ending December 31,	Capital Leases			Operating Leases
	2014	$	505		$	583
	2015	295			555
	2016	105			455
	2017	34			299
	2018	—			—
	Total future payments	939			$	1,892
	Less: Imputed interest	(78		)
	Future lease payments	$	861

INCENTIVE_COMPENSATION_Tables

INCENTIVE COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Summary of information regarding the Incentive Plan unit activity	'
	The following table summarizes information regarding the LTIP unit activity:
		Units		Weighted-average
				grant date fair value
	Unvested - November 7, 2012	—		$	—
	Granted units	146,000		23.01
	Forfeited units	(1,500	)	23.01
	Vested units	—		—
	Unvested - December 31, 2012	144,500		$	23.01
	Granted units	112,179		21.96
	Forfeited units	(20,700	)	22.09
	Units recaptured for tax withholdings	(13,034	)	23.01
	Vested units	(40,272	)	22.3
	Unvested - December 31, 2013	182,673		$	22.55
Schedule of Unit Based Compensation Expense	'
	The following table summarizes information regarding recognized compensation expense, which is included in general and administrative expense on our consolidated statements of operations (in thousands):
		Year Ended December 31,
		2013			2012		2011
	Unit-based compensation	$	2,186		$	630	$	—
Schedule of Employer's Matching Contributions	'
	The following table summarizes information regarding contributions and the expense recognized for the matching contributions, which is included in general and administrative expense on our consolidated statements of operations (in thousands):
		Year Ended December 31,
		2013			2012		2011
	Matching contributions expensed for employee savings plan	$	628		$	512	$	417

REVENUES_Tables

REVENUES (Tables)	12 Months Ended
	Dec. 31, 2013
Revenues [Abstract]	'
Schedule of revenues by category	'
	We had revenues consisting of the following categories (in thousands):
		Year ended December 31,
		2013		2012		2011
	Sales of natural gas	$	405,206	$	325,421	$	385,513
	Sales of NGLs and condensate	169,523		124,139		106,487
	Transportation, gathering and processing fees	59,392		46,113		30,102
	Other	601		456		1,047
	Total revenues	$	634,722	$	496,129	$	523,149

CONCENTRATION_OF_CREDIT_RISK_A1

CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE (Tables)	12 Months Ended
	Dec. 31, 2013
Risks and Uncertainties [Abstract]	'
Schedules of Concentration of Risk, Consolidated Revenue	'
	Our top ten customers for the years ended December 31, 2013, 2012 and 2011 represent the following percentages of consolidated revenue:
		Year Ended December 31,
		2013		2012		2011
	Top 10 customers	59.7	%	65.5	%	73.1	%
	The percentage of total consolidated revenue for each customer that exceeded 10% of total revenues for the years ended December 31, 2013, 2012 and 2011 was as follows:
		Year Ended December 31,
		2013		2012		2011
	Sherwin Alumina Company	11.7	%	11	%	15.5	%
	Formosa Hydrocarbons Co., Inc.	(a),(b)		24.3	%	20.8	%
	(a) Information is not provided for periods for which the customer or producer was less than 10% of our consolidated revenue.
	(b) Our contract with Formosa terminated on June 1, 2013.

SUPPLEMENTAL_CASH_FLOW_INFORMA1

SUPPLEMENTAL CASH FLOW INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2013
Supplemental Cash Flow Elements [Abstract]	'
Supplemental Cash Flow Information	'
		Year ended December 31,
		2013		2012		2011
	Supplemental Disclosures:
	Cash paid for interest, net of amounts capitalized	$	13,043	$	10,552	$	7,994
	Cash paid for taxes, net of refunds received	95		315		272
	Supplemental schedule of non-cash investing and financing activities:
	Accounts payable related to capital expenditures	4,946		40,707		10,862
	Change in value recognized in other comprehensive income	148		745		—
	Capital lease obligation	1,396		—		—
	Accrued distribution equivalent rights (DERs) on the LTIP units	279		—		—
	Other	$	704	$	—	$	—

SUPPLEMENTAL_SELECTED_QUARTERL1

SUPPLEMENTAL SELECTED QUARTERLY FINANCIAL INFORMATION (UNAUDITED) SUPPLEMENTAL SELECTED QUARTERLY FINANCIAL INFORMATION (UNAUDITED) (Tables)	12 Months Ended
	Dec. 31, 2013
Condensed Financial Information of Parent Company Only Disclosure [Abstract]	'
SCHEDULE OF SUPPLEMENTAL SELECTED QUARTERLY FINANCIAL INFORMATION (UNAUDITED)	'
	The following presents a summary of selected quarterly financial information (in thousands, except per unit data):
		Quarters ended
	2013	March 31			June 30			September 30			December 31					Total
	Revenues	$	144,250		$	154,703		$	160,629		$	175,140				$	634,722
	Gross operating margin	18,863			21,296			25,213			28,174					93,546
	(Loss) income from operations	(4,317		)	(2,831		)	(357		)	4,485					(3,020		)
	Net (loss) income	(6,382		)	(6,192		)	(4,069		)	673					(15,970		)
	General partner's interest in net loss	(128		)	(124		)	(81		)	14					(319		)
	Limited partners' interest in net loss	(6,254		)	(11,294		)	(17		)	244					(17,321		)
	Cash distribution attributable per quarter	9,973			9,986			9,987			13,755					43,701
	Basic net (loss) income per common unit	(0.26		)	(0.65		)	0.19			0.01
	Diluted net (loss) income per common unit	(0.26		)	(0.65		)	(0.14		)	0.01
	Basic and diluted net loss per subordinated unit	(0.26		)	(0.27		)	(0.19		)	0.01
		Quarters ended									Periods ended
	2012	March 31			June 30			September 30			October 1, 2012-			November 7, 2012-				Total
											November 6, 2012(1)			December 31, 2012(1)(2)
	Revenues	$	120,618		$	105,701		$	118,150		$	55,613		$	96,047			$	496,129
	Gross operating margin	21,416			18,698			15,078			6,741			9,707				71,640
	Income (loss) from operations	8,120			3,442			(2,686		)	(1,589		)	(3,998		)		3,289
	Net income (loss)	$	6,236		$	1,939		$	(4,041	)	$	(4,394	)	(4,228		)		(4,488		)
	Cash distribution attributable per quarter													5,982				5,982
	General partner's interest in net loss													(85		)		(85		)
	Limited partners' interest in net loss													(4,143		)		(4,143		)
	General partners' net loss per unit—basic and diluted													(0.17		)		(0.17		)
	Limited partners' net loss per unit—basic and diluted													(0.17		)		(0.17		)
	_______________________________________________________________________________
	-1	See Note 1 for a description of decreases in statements of operations during this period.
	-2	Represents results of Southcross Energy Partners, L.P. subsequent to our IPO on November 7, 2012.

ORGANIZATION_AND_DESCRIPTION_O1

ORGANIZATION AND DESCRIPTION OF BUSINESS (Details)	12 Months Ended
	Dec. 31, 2013
	segment
	plant
	mi
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Number of gas processing plants	3
Number of fractionation plants	2
Pipeline, length owned	2,740
Number of reportable segments	1

BASIS_OF_PRESENTATION_Details

BASIS OF PRESENTATION (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Basis of Presentation	'	'	'
Ownership interest in consolidated subsidiaries (as a percent)	100.00%	'	'
Long-Lived Assets	'	'	'
Expected useful lives of long-term supply and gas gathering contracts	'30 years	'	'
Accounts Receivable	'	'	'
Allowance for Doubtful Accounts Receivable, Current	$0	$0	'
Asset Retirement Obligation [Abstract]	'	'	'
Asset retirement obligation	$500,000	$0	$0

BASIS_OF_PRESENTATION_BASIS_OF1

BASIS OF PRESENTATION BASIS OF PRESENTATION - Interest Expense (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accounting Policies [Abstract]	'	'	'
Total interest costs	$14,047	$12,035	$7,157
Capitalized interest included in property, plant and equipment, net	-1,457	-6,268	-1,809
Interest expense	$12,590	$5,767	$5,348

BASIS_OF_PRESENTATION_BASIS_OF2

BASIS OF PRESENTATION BASIS OF PRESENTATION - Deferred Financing Costs (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Deferred Financing Costs [Roll Forward]	'	'	'
Deferred financing costs, beginning balance	$4,385	$2,154	'
Capitalization of deferred financing costs	2,139	5,178	'
Write-off of deferred financing costs	0	1,764	3,240
Amortization of deferred financing costs	1,287	1,183	882
Deferred financing costs, ending balance	$5,237	$4,385	$2,154

LIQUIDITY_CONSIDERATIONS_AND_E1

LIQUIDITY CONSIDERATIONS AND EQUITY OFFERINGS (Details) (USD $)

2 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

0 Months Ended

2 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 12, 2013

Dec. 31, 2013

Sep. 30, 2013

Mar. 27, 2013

Mar. 25, 2013

Nov. 07, 2012

Apr. 12, 2013

Mar. 27, 2013

Nov. 07, 2012

Dec. 31, 2013

Apr. 12, 2013

Apr. 12, 2013

Apr. 12, 2013

Jan. 29, 2014

Apr. 12, 2013

Apr. 12, 2013

Mar. 27, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 12, 2013

Apr. 12, 2013

Senior Secured Credit Facility [Member]

Senior Secured Credit Facility [Member]

Senior Secured Credit Facility [Member]

Senior Secured Credit Facility [Member]

Senior Secured Credit Facility [Member]

Senior Secured Credit Facility [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Southcross LLC [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Subsequent Event [Member]

Subsequent Event [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

Common Units [Member]

Senior Secured Credit Facility [Member]

Senior Secured Credit Facility [Member]

Southcross Energy Partners LLC [Member]

mi

Series A Convertible Preferred Units [Member]

Subsequent Event [Member]

Subsequent Event [Member]

item

Series A Convertible Preferred Units [Member]

Southcross Energy Partners LLC [Member]

Schedule of Capitalization, Long-term Debt [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization of financing costs

'

$1,287,000

$1,183,000

$882,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Remaining available borrowings capacity

'

'

'

'

'

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted cash

'

'

'

'

'

'

'

'

'

'

'

'

'

30,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity

'

'

'

'

'

350,000,000

'

250,000,000

350,000,000

350,000,000

50,000,000

31,500,000

75,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Leverage ratio for one quarter

'

'

'

'

4.25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Leverage ratio for two consecutive quarters

'

'

'

'

4.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total capital infusion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Number of succeeding quarters relating to estimated quarterly distributions used for determination of conversion of preferred units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

'

'

'

'

'

'

Amount deposited by general partner into the Collateral Account

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,000,000

'

3,000,000

17,400,000

'

'

'

'

Pipeline, length of extension

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90

'

'

'

'

'

'

'

'

'

'

Maximum adjusted consolidated total leverage ratio

'

'

'

'

'

6.75

7.25

'

'

'

'

'

'

'

'

'

'

5.75

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance under public offering

'

'

187,764,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Units issued and sold

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,715,000

Share price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$22.86

'

$22.86

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

39,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Contributions from general partner

262,826,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

800,000

'

6,713,000

'

800,000

0

0

'

'

Additional capital contributions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$800,000

'

'

'

'

'

'

'

'

Ownership interest held by limited partners (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.00%

'

ACQUISITIONS_Details

ACQUISITIONS (Details) (USD $)

1 Months Ended

2 Months Ended

3 Months Ended

10 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

4 Months Ended

0 Months Ended

12 Months Ended

Nov. 06, 2012

Dec. 31, 2012

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Nov. 06, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 02, 2011

Sep. 30, 2011

Dec. 31, 2011

Sep. 02, 2011

Sep. 02, 2011

Dec. 31, 2012

Dec. 31, 2012

EAI [Member]

EAI [Member]

EAI [Member]

EAI [Member]

EAI [Member]

Pro Forma [Member]

Pro Forma [Member]

mi

Minimum [Member]

Maximum [Member]

EAI [Member]

in

in

ACQUISITIONS

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Length of natural gas pipeline assets acquired (in miles)

'

'

'

'

'

'

'

'

'

'

'

'

'

388

'

'

'

'

'

'

Diameter of natural gas pipeline assets acquired (in inches)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

16

'

'

Goodwill

'

'

'

'

'

'

'

'

'

'

'

'

'

$0

'

'

'

'

'

'

Purchase Price - Cash

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments to Acquire Businesses, Net of Cash Acquired

'

'

'

'

'

'

'

'

'

'

'

'

21,777,000

21,777,000

'

'

'

'

'

'

Fair value of identifiable assets acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current assets

'

'

'

'

'

'

'

'

'

'

'

'

'

3,374,000

'

'

'

'

'

'

Property, plant and equipment

'

'

'

'

'

'

'

'

'

'

'

'

'

19,300,000

'

'

'

'

'

'

Intangible assets

'

'

'

'

'

'

'

'

'

'

'

'

'

1,700,000

'

'

'

'

'

'

Total assets acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

24,374,000

'

'

'

'

'

'

Current liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

2,597,000

'

'

'

'

'

'

Net identifiable assets acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

21,777,000

'

'

'

'

'

'

Transaction costs associated with acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,000

'

'

'

'

'

Unaudited Pro Forma Information

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenue

55,613,000

96,047,000

175,140,000

160,629,000

154,703,000

144,250,000

118,150,000

105,701,000

120,618,000

'

634,722,000

496,129,000

523,149,000

'

'

11,000,000

'

'

523,149,000

'

Net income

-4,394,000

-4,228,000

673,000

-4,069,000

-6,192,000

-6,382,000

-4,041,000

1,939,000

6,236,000

-260,000

-15,970,000

-4,488,000

7,539,000

'

'

800,000

'

'

7,539,000

'

Net loss attributable to common unitholders

'

'

'

'

'

'

'

'

'

'

'

-22,910,000

-8,145,000

'

'

'

'

'

-8,145,000

'

Basic and diluted net loss per subordinated unit (in dollars per share)

'

($0.17)

'

'

'

'

'

'

'

'

($0.71)

($19.12)

($6.79)

'

'

'

'

'

($6.79)

'

Total revenue

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

548,152,000

Net income

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,789,000

Net loss attributable to common unitholders

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

($7,895,000)

Net loss per unit - (basic and diluted)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

($6.59)

EARNINGS_PER_LIMITED_PARTNER_U2

EARNINGS PER LIMITED PARTNER UNIT AND DISTRIBUTIONS (Details) (USD $)

1 Months Ended

2 Months Ended

3 Months Ended

9 Months Ended

10 Months Ended

12 Months Ended

In Thousands, except Share data, unless otherwise specified

Nov. 06, 2012

Dec. 31, 2012

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Nov. 06, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Earnings Per Unit of the Partnership

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net loss

($4,394)

($4,228)

$673

($4,069)

($6,192)

($6,382)

($4,041)

$1,939

$6,236

'

($260)

($15,970)

($4,488)

$7,539

Series A Preferred Unit in-kind distribution and fair value adjustment

'

'

'

'

'

'

'

'

'

-1,670

'

-1,670

'

'

Net loss attributable to partners

'

-4,228

'

'

'

'

'

'

'

'

'

-17,640

'

'

Interest in net loss

'

'

'

'

'

'

'

'

'

'

'

'

-22,910

-8,145

Basic and diluted net loss per common unit (in dollars per share)

'

($0.17)

'

'

'

'

'

'

'

'

'

($0.71)

($19.12)

($6.79)

General Partner [Member]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earnings Per Unit of the Partnership

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net loss

'

-85

14

-81

-124

-128

'

'

'

'

'

-319

-85

'

Series A Preferred Unit in-kind distribution and fair value adjustment

'

'

'

'

'

'

'

'

'

'

'

-1,670

'

'

Basic and diluted net loss per common unit (in dollars per share)

'

($0.17)

'

'

'

'

'

'

'

'

'

'

($0.17)

'

Common Units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earnings Per Unit of the Partnership

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net loss

'

-2,072

'

'

'

'

'

'

'

'

'

-7,829

'

'

Net income (loss) allocated to limited partners

'

-2,072

'

'

'

'

'

'

'

'

'

-8,683

'

'

Interest in net loss

'

-2,072

'

'

'

'

'

'

'

'

'

-8,683

'

'

Dilutive interest in net loss

'

-2,072

'

'

'

'

'

'

'

'

'

-8,683

'

'

Weighted-average units - basic (in shares)

'

12,213,713

'

'

'

'

'

'

'

'

'

12,224,997

'

'

Weighted-average units - diluted (in shares)

'

12,213,713

'

'

'

'

'

'

'

'

'

12,224,997

'

'

Unvested common units excluded in computation of diluted per-unit amounts (in shares)

'

'

'

'

'

'

'

'

'

'

'

10,092

144,500

'

Subordinated Units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earnings Per Unit of the Partnership

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net loss

'

-2,071

'

'

'

'

'

'

'

'

'

-7,822

'

'

Net income (loss) allocated to limited partners

'

-2,071

'

'

'

'

'

'

'

'

'

-8,638

'

'

Interest in net loss

'

-2,071

'

'

'

'

'

'

'

'

'

-8,638

'

'

Dilutive interest in net loss

'

($2,071)

'

'

'

'

'

'

'

'

'

($8,638)

'

'

Weighted-average units - basic (in shares)

'

12,213,713

'

'

'

'

'

'

'

'

'

12,213,713

'

'

Weighted-average units - diluted (in shares)

'

12,213,713

'

'

'

'

'

'

'

'

'

12,213,713

'

'

Basic and diluted net loss per subordinated unit (in dollars per share)

'

($0.17)

'

'

'

'

'

'

'

'

'

($0.71)

'

'

Series A Convertible Preferred Units [Member]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earnings Per Unit of the Partnership

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unvested common units excluded in computation of diluted per-unit amounts (in shares)

'

'

'

'

'

'

'

'

'

'

'

1,233,117

'

'

EARNINGS_PER_LIMITED_PARTNER_U3

EARNINGS PER LIMITED PARTNER UNIT AND DISTRIBUTIONS (Details 2) (USD $)

2 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

10 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Nov. 14, 2013

15-May-13

Apr. 12, 2013

Dec. 31, 2013

Nov. 06, 2012

Dec. 31, 2011

Dec. 31, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jun. 30, 2013

Jun. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jun. 30, 2013

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jun. 30, 2013

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jun. 30, 2013

Jun. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

15-May-13

Apr. 12, 2013

Apr. 12, 2013

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Jun. 30, 2013

Apr. 12, 2013

Phantom Units

General Partner [Member]

General Partner [Member]

General Partner [Member]

Limited Partners [Member]

Limited Partners [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

In-kind [Member]

Maximum [Member]

Maximum [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Pro-rated for issuance of 29,925 general partner units

Pro-rated for issuance of 5,075 general partner units

Subsequent Event [Member]

Subsequent Event [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Cash [Member]

Cash [Member]

Senior Secured Credit Facility [Member]

In-kind [Member]

In-kind [Member]

In-kind [Member]

In-kind [Member]

In-kind [Member]

In-kind [Member]

In-kind [Member]

In-kind [Member]

In-kind [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Pro-rated for issuance of 29,925 general partner units

Pro-rated for issuance of 5,075 general partner units

Common Units

Common Units

Common Units

Common Units

Common Units

Common Units

Common Units

Subordinated

Subordinated

Subordinated

Subordinated

Subordinated

Subordinated

Subordinated

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

Common Units [Member]

Pro-rated for issuance of 29,925 general partner units

Pro-rated for issuance of 5,075 general partner units

Pro-rated for issuance of 29,925 general partner units

Pro-rated for issuance of 5,075 general partner units

Subsequent Event [Member]

Distributions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'45 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum quarterly distribution (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

$0.40

$0.40

$0.24

$0.40

$0.35

$0.20

$0.40

$0.40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.40

$0.40

$0.35

$0.20

'

'

'

'

'

'

'

Minimum annual distribution (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

'

'

'

$1.60

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1.60

$1.60

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest held by general partners (as a percent)

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive distribution rights as a percentage of distribution from operating surplus in excess of stated per unit amount (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount used to calculate additional distribution percentage (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.46

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution paid in cash

'

$43,701,000

$5,982,000

'

'

'

'

'

'

$13,755,000

$9,975,000

$9,973,000

$5,982,000

$9,987,000

$10,000

$1,000

'

'

$289,000

$199,000

$199,000

$120,000

$214,000

$10,000

$1,000

$8,581,000

$4,890,000

$4,888,000

$2,931,000

$4,888,000

$0

$0

$4,885,000

$4,886,000

$4,886,000

$2,931,000

$4,885,000

$0

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Annual distribution rate (percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7.00%

'

'

'

'

'

'

Issuance of general partner units

'

'

'

'

5,075

29,925

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

248,675

1,466,325

'

'

'

'

'

'

'

'

'

'

'

'

In-kind unit distribution

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

30,971

30,439

22,276

2,199

'

632

621

454

45

'

'

In-kind unit distribution, fair value

'

0

'

'

'

'

-33,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

558,000

511,000

512,000

51,000

'

11,000

10,000

10,000

1,000

'

'

Unvested common units excluded in computation of diluted per-unit amounts (in shares)

'

'

'

'

'

'

'

143,220

274,762

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred units agreed to be sold

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,500,000

'

Aggregate distributions to unitholders

'

35,928,000

'

63,800

'

'

742,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total capital infusion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$40,000,000

'

'

'

'

'

'

'

'

'

'

'

Series A convertible preferred units issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,715,000

FINANCIAL_INSTRUMENTS_Details

FINANCIAL INSTRUMENTS (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Interest rate swap liability	'	'	'
Fair value of financial instruments	'	'	'
Derivative, notional value	$150,000,000	'	'
Derivative, fixed interest rate	0.54%	'	'
Derivative liability, non-current	'	300,000	'
Recurring basis | Significant Other Observable Inputs (Level 2) | Interest rate swap liability	'	'	'
Fair value of financial instruments	'	'	'
Fair value measurement	263,000	638,000	'
Derivatives designated as hedging instruments | Interest rate swap liability	'	'	'
Fair value of financial instruments	'	'	'
Change in value recognized in other comprehensive loss - effective portion	-148,000	-745,000	0
Hedging losses related to interest rate swap contract	300,000	'	'
Period hedging losses will be reclassified from AOCI to earnings	'12 months	'	'
Derivatives designated as hedging instruments | Interest rate cap	'	'	'
Fair value of financial instruments	'	'	'
Loss reclassified from accumulated other comprehensive loss to interest expense	$415,000	$268,000	$0
LIBOR | Interest rate swap liability	'	'	'
Fair value of financial instruments	'	'	'
Derivative, term for variable interest rate	'1 month	'	'

FINANCIAL_INSTRUMENTS_Details_

FINANCIAL INSTRUMENTS (Details 2) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MMBTU	item
	item
Derivatives	'	'	'
Number of outstanding month-ahead swap contracts	'	0	'
Volume of month-ahead swap contracts (in MMBtu)	33,722	'	'
Unrealized loss on interest rate cap	$120	($141)	($21)
Interest rate cap contract	'	'	'
Derivatives	'	'	'
Realized gain /(loss) on derivatives	108	82	147
Unrealized loss on interest rate cap	0	141	21
Commodity Swaps	'	'	'
Derivatives	'	'	'
Derivative Asset, Fair Value, Gross Asset	140	'	'
Derivative Liability, Fair Value, Gross Liability	-20	'	'
Derivative Liability, Amount Offset Against Derivative Asset	20	'	'
Commodity swaps, net	120	'	'
Realized gain /(loss) on derivatives	-659	-12	179
Unrealized loss on interest rate cap	$120	$0	$0

LONGLIVED_ASSETS_Details

LONG-LIVED ASSETS (Details) (USD $)	1 Months Ended	3 Months Ended	12 Months Ended
	Jan. 31, 2013	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Property, plant and equipment	'	'	'	'	'
Total property, plant and equipment	'	'	$644,356,000	$514,828,000	'
Accumulated depreciation and amortization	'	'	-79,908,000	-46,466,000	'
Property, plant and equipment, net	'	'	575,795,000	550,603,000	'
Depreciation expense	'	'	33,548,000	18,977,000	12,345,000
Capitalized interest included in property, plant and equipment, net	'	'	-1,457,000	-6,268,000	-1,809,000
Capital leases	'	'	0	0	'
Property, plant and equipment, service charges	4,600,000	'	'	'	'
Insurance recoveries	'	1,000,000	'	'	'
Insurance claims deductible amount	300,000	'	'	'	'
Intangible assets, net	'	'	1,568,000	1,624,000	'
Expected useful lives of contracts	'	'	'30 years	'	'
Property, plant and equipment excluding construction in progress and land and other	'	'	'	'	'
Property, plant and equipment	'	'	'	'	'
Property, plant and equipment, net	'	'	564,448,000	468,362,000	'
Pipelines	'	'	'	'	'
Property, plant and equipment	'	'	'	'	'
Estimated Useful life	'	'	'30 years	'	'
Total property, plant and equipment	'	'	344,721,000	250,177,000	'
Gas processing, treating and other plants	'	'	'	'	'
Property, plant and equipment	'	'	'	'	'
Estimated Useful life	'	'	'15 years	'	'
Total property, plant and equipment	'	'	254,133,000	221,594,000	'
Compressors	'	'	'	'	'
Property, plant and equipment	'	'	'	'	'
Estimated Useful life	'	'	'7 years	'	'
Total property, plant and equipment	'	'	20,030,000	19,241,000	'
Rights of way and easements	'	'	'	'	'
Property, plant and equipment	'	'	'	'	'
Estimated Useful life	'	'	'15 years	'	'
Total property, plant and equipment	'	'	20,729,000	20,729,000	'
Furniture, fixtures & equipment	'	'	'	'	'
Property, plant and equipment	'	'	'	'	'
Estimated Useful life	'	'	'5 years	'	'
Total property, plant and equipment	'	'	3,347,000	3,087,000	'
Capital lease vehicles	'	'	'	'	'
Property, plant and equipment	'	'	'	'	'
Total property, plant and equipment	'	'	1,396,000	0	'
Capital lease vehicles | Minimum [Member]	'	'	'	'	'
Property, plant and equipment	'	'	'	'	'
Estimated Useful life	'	'	'3 years	'	'
Capital lease vehicles | Maximum [Member]	'	'	'	'	'
Property, plant and equipment	'	'	'	'	'
Estimated Useful life	'	'	'5 years	'	'
Construction in progress	'	'	'	'	'
Property, plant and equipment	'	'	'	'	'
Property, plant and equipment, net	'	'	6,039,000	77,011,000	'
Land and other	'	'	'	'	'
Property, plant and equipment	'	'	'	'	'
Property, plant and equipment, net	'	'	$5,308,000	$5,230,000	'

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (USD $)

12 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

2 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

10 Months Ended

12 Months Ended

3 Months Ended

0 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 27, 2013

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Jan. 29, 2014

Apr. 12, 2013

Dec. 31, 2013

Sep. 30, 2013

Aug. 06, 2013

Apr. 12, 2013

Dec. 31, 2012

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Mar. 27, 2013

Mar. 25, 2013

Nov. 07, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Nov. 06, 2012

Dec. 31, 2012

Dec. 31, 2013

Apr. 12, 2013

Mar. 27, 2013

Dec. 31, 2012

Nov. 07, 2012

Dec. 31, 2013

Jun. 30, 2013

Apr. 12, 2013

Jan. 29, 2014

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

Subsequent Event [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Facility, due November 2017 [Member]

Credit Agreement, due June 2014 [Member]

Credit Agreement, due June 2014 [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Southcross LLC [Member]

Series A Convertible Preferred Units [Member]

Common Units [Member]

Credit Facility

mi

right

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Actual [Member]

Actual [Member]

Forecast [Member]

Credit Facility, due November 2017 [Member]

Southcross Energy Partners LLC [Member]

Series A Convertible Preferred Units [Member]

Subsequent Event [Member]

31-Mar-14

30-Jun-14

30-Sep-14

31-Dec-14

March 31, 2015 and thereafter

Southcross Energy Partners LLC [Member]

Subsequent Event [Member]

LONG TERM DEBT

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Debt covenant, limitation on aggregate consideration for business acquisition

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$40,000,000

Pipeline, length of extension

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90

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'

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'

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'

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General Partners' Capital Account, Units Issued

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35,000

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Units issued and sold

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1,715,000

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Preferred units agreed to be sold

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1,500,000

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Total

267,300,000

191,000,000

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191,000,000

267,300,000

'

267,300,000

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Current maturities of long-term debt

0

0

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Total long-term debt

267,300,000

191,000,000

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Description of variable rate basis

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'LIBOR

'LIBOR

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'LIBOR

'LIBOR

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Basis spread on variable rate (as a percent)

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3.25%

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4.50%

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3.25%

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Weighted-average interest rate (as a percent)

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4.44%

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4.44%

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3.95%

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Borrowings

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267,300,000

'

267,300,000

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191,000,000

31,300,000

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'

26,300,000

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Remaining available borrowings capacity

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100,000

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100,000

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Restricted cash

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30,100,000

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'

Average borrowings outstanding

243,900,000

230,400,000

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'

Maximum outstanding borrowings

267,300,000

270,000,000

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'

'

'

Maximum borrowing capacity

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'

350,000,000

'

350,000,000

250,000,000

350,000,000

350,000,000

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'

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'

'

50,000,000

31,500,000

'

75,000,000

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'

'

'

Amount deposited by general partner into the Collateral Account

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'

10,000,000

3,000,000

17,400,000

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Debt Instrument, Fee Amount

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1,500,000

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600,000

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'

Leverage ratio for one quarter

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4.25

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'

Leverage ratio for two consecutive quarters

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4.5

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'

Basis spread on variable rate until the Target Leverage Ratio is achieved (as a percent)

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4.50%

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'

Maximum growth capital expenditures for the remainder of 2013

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25,000,000

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'

'

Maximum growth capital expenditures for the 18 months ended June 30, 2015

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25,000,000

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'

'

'

Increase in amount deposited by general partner into the Collateral Account

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28,000,000

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'

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'

'

'

'

'

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'

'

'

Maximum quarterly distributions until the Target Leverage Ratio is achieved (in dollars per share)

'

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$0.40

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'

Investment amount required to make by Southcross Energy LLC and/or General Partner

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40,000,000

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'

'

'

'

'

Minimum Consolidated EBITDA

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9,000,000

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'

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'

'

'

'

'

'

Amount Deposited into Collateral Account by Utilizing Cure Rights

'

'

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2,700,000

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'

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'

'

'

'

'

'

'

'

'

'

'

'

Maximum adjusted consolidated total leverage ratio

'

'

'

'

'

'

'

5.75

'

'

'

'

'

'

6.75

7.25

'

'

'

'

6.25

5.25

5

4.75

4.5

5.3

6.5

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'

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'

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'

'

'

5.75

Minimum consolidated interest coverage ratio

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'

'

2.25

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'

'

'

'

'

'

'

3.13

'

2.5

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'

'

'

'

'

'

'

'

'

Number of times the right can be exercised under the Financial Covenants Default

'

'

'

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2

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'

'

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'

'

'

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'

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'

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'

'

'

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'

'

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'

Leverage ratio

'

'

'

'

'

'

'

'

'

4.5

4.75

'

'

'

'

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'

'

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'

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'

'

'

'

'

'

'

'

'

'

'

'

'

Loss on extinguishment of debt

$0

$1,764,000

$3,240,000

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'

'

COMMITMENTS_AND_CONTINGENT_LIA2

COMMITMENTS AND CONTINGENT LIABILITIES (Details) (USD $)	3 Months Ended	12 Months Ended
	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
		item
Legal Matters	'	'	'	'
Number of pending proceedings	'	0	'	'
Litigation accrual	'	$0	$0	'
Amortization expense related to capital leases	'	500,000	'	'
Future minimum annual rental commitments under capital leases	'	'	'	'
2014	'	505,000	'	'
2015	'	295,000	'	'
2016	'	105,000	'	'
2017	'	34,000	'	'
2018	'	0	'	'
Total future payments	'	939,000	'	'
Less: Imputed interest	'	-78,000	'	'
Future lease payments	'	861,000	'	'
Capital lease obligation	0	1,396,000	0	0
Future minimum annual rental commitments under our operating leases	'	'	'	'
2014	'	583,000	'	'
2015	'	555,000	'	'
2016	'	455,000	'	'
2017	'	299,000	'	'
2018	'	0	'	'
Total	'	1,892,000	'	'
Expenses associated with operating leases	'	'	'	'
Expenses associated with operating leases	'	$1,500,000	$2,200,000	$1,500,000

COMMITMENTS_AND_CONTINGENT_LIA3

COMMITMENTS AND CONTINGENT LIABILITIES (Details 2) (USD $)	3 Months Ended	12 Months Ended
	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Purchase commitments	'	'	'	'
Capital lease obligation	$0	$1,396,000	$0	$0
Equipment related to capital projects	'	'	'	'
Purchase commitments	'	'	'	'
Commitments	'	900,000	'	'
Other planned capital projects	'	'	'	'
Purchase commitments	'	'	'	'
Commitments	'	$0	'	'

TRANSACTIONS_WITH_RELATED_PART1

TRANSACTIONS WITH RELATED PARTIES (Details) (USD $)

12 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Apr. 12, 2013

Dec. 31, 2013

Jun. 30, 2013

Dec. 31, 2013

Apr. 12, 2013

Apr. 12, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Aug. 06, 2009

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

officer

Series A Convertible Preferred Units [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Charlesbank

Charlesbank

Charlesbank

Charlesbank

Charlesbank

Charlesbank

Charlesbank

Charlesbank

Charlesbank

Affiliates of Wells Fargo Bank

Affiliates of Wells Fargo Bank

Affiliates of Wells Fargo Bank

director

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Series A Convertible Preferred Units [Member]

Common Units [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Series A Convertible Preferred Units [Member]

Subsequent Event [Member]

Related Party Transaction [Line Items]

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Related party transaction, management fees

'

'

'

'

'

'

'

'

'

'

'

'

'

$600,000

$500,000

$600,000

'

'

'

Related party transaction, expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

68,000

109,000

'

'

'

Related party transaction, amount paid to related party

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

'

'

Number of Officers

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Directors

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expenses incurred from transactions with related party

'

'

24,800,000

'

'

'

'

500,000

'

'

'

'

'

'

'

'

'

'

'

Units issued and sold

'

'

'

'

'

'

1,715,000

'

'

'

'

'

'

'

'

'

'

'

'

Cash purchase price (in dollars per unit)

'

$22.86

'

'

'

$22.86

'

'

'

'

'

'

$1

'

'

'

'

'

'

Preferred units agreed to be sold

'

'

'

1,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Series A preferred units outstanding

'

'

'

'

221,884

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fees paid to related party

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,800,000

5,900,000

1,000,000

Related party transaction, annual management fee

'

'

'

'

'

'

'

'

'

$600,000

$600,000

$600,000

'

'

'

'

'

'

'

SERIES_A_CONVERTIBLE_PREFERRED1

SERIES A CONVERTIBLE PREFERRED UNITS SERIES A CONVERTIBLE PREFERRED UNITS (Details) (USD $)	9 Months Ended	12 Months Ended	0 Months Ended		3 Months Ended		0 Months Ended	12 Months Ended	0 Months Ended
	Dec. 31, 2013	Dec. 31, 2013	Apr. 12, 2013	Apr. 12, 2013	Jun. 30, 2013	Apr. 12, 2013	Apr. 12, 2013	Dec. 31, 2013	Apr. 12, 2013	Apr. 12, 2013	Apr. 12, 2013
			Series A Convertible Preferred Units [Member]	Series A Convertible Preferred Units [Member]	Series A Convertible Preferred Units [Member]	Senior Secured Credit Facility [Member]	General Partner [Member]	General Partner [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Common Units [Member]
				Southcross Energy Partners LLC [Member]	Southcross Energy Partners LLC [Member]	Series A Convertible Preferred Units [Member]			Series A Convertible Preferred Units [Member]	General Partner [Member]	Subsequent Event [Member]
				vote					item		Series A Convertible Preferred Units [Member]
											Southcross Energy Partners LLC [Member]
Capital Unit [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Share price	'	'	$22.86	$22.86	'	'	'	'	'	'	'
Preferred units agreed to be sold	'	'	'	'	1,500,000	'	'	'	'	'	'
Units issued and sold	'	'	'	'	'	'	'	'	'	'	1,715,000
Total capital infusion	'	'	'	'	'	$40,000,000	'	'	'	'	'
Proceeds from issuance of units	'	'	39,200,000	'	'	'	'	'	'	'	'
Additional capital contributions	'	'	'	'	'	'	800,000	'	'	'	'
Ownership interest held by limited partners (as a percent)	'	'	'	'	'	'	'	'	'	2.00%	'
Series A Preferred Unit in-kind distribution and fair value adjustment	$1,670,000	$1,670,000	'	'	'	'	'	$1,670,000	'	'	'
Voting rights per preferred unit	'	'	'	1	'	'	'	'	'	'	'
Rate per outstanding unit per quarter for preferred units to be distributed as in-kind distributions (in dollars per unit)	'	'	0.4	'	'	'	'	'	0.4	'	'
Rate per year of the per unit purchase price for preferred units to be distributed as in-kind distributions (as a percent)	'	'	7.00%	'	'	'	'	'	'	'	'
Rate per unit per quarter used for determination of cash distributions (in dollars per unit)	'	'	0.4	'	'	'	'	'	0.4	'	'
Number of common units to be issued on conversion of one preferred unit	'	'	'	'	'	'	'	'	1	'	'
Number of succeeding quarters relating to estimated quarterly distributions used for determination of conversion of preferred units	'	'	'	'	'	'	'	'	4	'	'
Trailing period considered for the conversion of units	'	'	'	'	'	'	'	'	'30 days	'	'
Percentage of the daily volume-weighted average trading price of the common units that the Unit Purchase Price must exceed in order for the units to be convertible	'	'	'	'	'	'	'	'	130.00%	'	'
Number of common units from which the average daily trading volume of common units must exceed for trailing period in order for the units to be convertible	'	'	'	'	'	'	'	'	40,000	'	'
Collective value of common units as a percentage of preferred units to be convertible on satisfaction of specified condition	'	'	'	'	'	'	'	'	110.00%	'	'

PARTNERS_CAPITAL_AND_MEMBERS_E1

PARTNERS' CAPITAL AND MEMBERS' EQUITY (Details) (USD $)

2 Months Ended

10 Months Ended

12 Months Ended

0 Months Ended

2 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

2 Months Ended

0 Months Ended

1 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Dec. 31, 2012

Nov. 06, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 12, 2013

Apr. 12, 2013

Apr. 12, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 12, 2013

Jan. 31, 2014

Dec. 31, 2012

Dec. 31, 2013

Nov. 26, 2012

Nov. 26, 2011

Feb. 28, 2014

Dec. 31, 2011

Dec. 31, 2011

Mar. 20, 2012

Aug. 06, 2009

Aug. 06, 2009

Dec. 31, 2013

Nov. 07, 2012

Dec. 31, 2011

Dec. 31, 2011

Series A Convertible Preferred Units [Member]

Subsequent Event [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

Common Units

Common Units

Common units [Member]

Common units [Member]

Common units [Member]

Class A

Class B

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Series A Convertible Preferred Units [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

item

Charlesbank

Time-vesting units

General Partner [Member]

Class A

Class B

Limited Partners' Capital Account [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public offering, amount authorized

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$675,000,000

'

'

'

'

'

'

'

'

'

Units authorized for public offering

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,200,000

'

'

'

'

'

'

'

'

'

Ownership interest held by limited partners (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from public offering, net of underwriters' discounts and structuring fees

'

'

'

187,764,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

148,800,000

'

'

'

'

'

'

168,000,000

'

'

Estimated cost of public offering

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

400,000

'

'

'

'

'

'

'

'

'

Number of units issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12,213,713

12,253,985

'

1,350,000

'

'

'

'

'

'

'

'

'

'

Net proceeds

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25,200,000

'

'

'

'

'

'

'

'

'

'

'

Units reacquired from the Predecessor

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,350,000

'

'

'

'

'

'

'

'

'

'

'

General Partner, units outstanding

'

'

'

'

'

'

'

'

498,518

534,638

498,518

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capital contribution

262,826,000

'

'

'

'

'

'

800,000

6,713,000

800,000

0

0

'

'

43,274,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase of general partner units

'

'

'

'

'

'

'

'

'

'

'

'

'

188,582

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of members of the Predecessor's management team that purchased units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

'

'

'

'

'

Cash purchase price (in dollars per unit)

'

'

'

'

'

$22.86

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1

'

'

'

'

Common equity, units authorized

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,415,729

57,279

'

'

'

'

'

'

'

Common units unvested

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

217,483

34,367

Common units outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,415,729

57,279

'

'

'

'

'

'

'

Sale of stock (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1

$1

Par value of units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1

$1

Vesting period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

Amount of incentive units repurchased and retired

$25,205,000

$15,300,000

'

'

'

'

'

'

'

'

'

'

'

'

$25,205,000

'

'

'

'

'

'

$15,300,000

'

'

'

'

'

'

Rate per outstanding unit per quarter for preferred units to be distributed as in-kind distributions (in dollars per unit)

'

'

'

'

'

0.4

0.4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Rate per unit per quarter used for determination of cash distributions (in dollars per unit)

'

'

'

'

'

0.4

0.4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

SOUTHCROSS_ENERGY_LLC_PREFERRE1

SOUTHCROSS ENERGY LLC PREFERRED UNITS (Details) (Southcross Energy Partners LLC [Member], USD $)

Nov. 07, 2012

Dec. 31, 2011

Nov. 07, 2012

Dec. 31, 2011

Jun. 10, 2011

Jun. 10, 2011

Nov. 26, 2012

Nov. 07, 2012

Jun. 26, 2012

Mar. 20, 2012

Mar. 20, 2012

Nov. 07, 2012

Nov. 07, 2012

Jun. 26, 2012

In Millions, except Share data, unless otherwise specified

Preferred units

Preferred units

Redeemable preferred units

Redeemable preferred units

Redeemable preferred units

Redeemable preferred units

Series B redeemable preferred units

Series B redeemable preferred units

Series B redeemable preferred units

Series B redeemable preferred units

Series B redeemable preferred units

Series C redeemable preferred units

Series C redeemable preferred units

Series C redeemable preferred units

Charlesbank and most of existing investors

Charlesbank and certain predecessor investors

Charlesbank and certain predecessor investors

Affiliate of Wells Fargo Securities, LLC

Charlesbank, other institutional investors, and certain predecessor investors

Charlesbank, other institutional investors, and certain predecessor investors

Southcross Energy LLC preferred units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Series A convertible preferred units outstanding

11,850,374

11,850,374

'

'

'

'

'

3,350,000

'

'

'

3,000,000

'

'

Par value of preferred units (in dollars per unit)

$10

$10

'

'

$10

'

'

$10

'

'

'

'

$10

'

Rate at which value accrues (as a percent)

10.00%

10.00%

'

'

18.00%

'

'

18.00%

'

'

'

'

18.00%

'

Number of preferred units conveyed in IPO

0

'

0

'

'

'

'

0

'

'

'

0

'

'

Cumulative right to receive future cash distributions

$43.30

$31.80

$3.90

$1.60

'

'

$4.40

$3.80

'

'

'

'

$1.40

'

Contributed capital

'

'

'

'

'

$15

'

'

$7.50

$25.30

$10

'

'

$30

Series A convertible preferred units issued

'

'

'

'

'

1,500,000

'

'

750,000

2,530,000

1,000,000

'

'

3,000,000

Units redeemed

'

'

'

'

'

'

2,490,000

'

'

'

'

'

'

'

INCENTIVE_COMPENSATION_Details

INCENTIVE COMPENSATION (Details) (USD $)

12 Months Ended

2 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

2 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Apr. 02, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Phantom Units

Phantom Units

Phantom Units

Phantom Units

EEUs

EEUs

EEUs

Incentive Plan

Incentive Plan

Employee Savings Plan

Employee Savings Plan

Employee Savings Plan

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Minimum [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Southcross Energy Partners LLC [Member]

Unit based compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Vesting period

'

'

'

'

'

'

'

'

'3 years

'

'

'3 years

'

'

'

Units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unvested at the beginning of the period (in shares)

'

'

'

'

'

'

'

'

'

'

0

144,500

'

'

'

Granted units (in shares)

'

'

'

'

'

'

'

'

'

'

146,000

112,179

'

'

'

Forfeited units (in shares)

'

'

'

'

'

'

'

'

'

'

-1,500

-20,700

'

'

'

Units recaptured for tax withholdings (in shares)

'

'

'

'

'

'

'

'

'

'

'

-13,034

'

'

'

Vested units (in shares)

'

'

'

0

-40,272

'

'

'

'

'

'

'

'

'

'

Unvested at the end of the period (in shares)

'

'

'

'

'

'

'

'

'

'

144,500

182,673

'

'

'

Weighted-average grant date fair value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unvested at the beginning of the period (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

$0

$23.01

'

'

'

Granted units (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

$23.01

$21.96

'

'

'

Forfeited units (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

$23.01

$22.09

'

'

'

Units recaptured for tax withholdings (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

'

$23.01

'

'

'

Vested units (in dollars per share)

'

'

'

$0

$22.30

'

'

'

'

'

'

'

'

'

'

Unvested at the end of the period (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

$23.01

$22.55

'

'

'

Fair value

'

'

'

'

$0

$0

'

'

'

'

'

$2,500,000

'

'

'

Unamortized compensation expense

'

'

'

'

'

'

'

'

'

'

'

3,600,000

'

'

'

Period of amortization of compensation expense

'

'

'

'

'

'

'

'

'

'

'

'3 years

'

'

'

Units available for issuance (in shares)

'

'

'

'

'

'

'

'

'

'

'

1,527,055

'

'

'

Percentage of voting power that must change hands resulting in a change in control for the awards to vest

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

Number of authorized awards (in units)

'

'

'

10,832

10,832

10,832

'

'

'

'

'

'

'

'

'

Number of issued awards (in units)

'

'

'

'

10,832

10,832

'

'

'

'

'

'

'

'

'

Number of units grated

'

'

'

'

'

'

'

15,000

'

'

'

'

'

'

'

Unit-based compensation expense

2,186,000

630,000

0

'

'

'

'

'

600,000

400,000

'

'

'

'

'

Employer matching contribution, percent of employees' contribution

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

Employer matching contribution, percent of employees' gross pay

'

'

'

'

'

'

'

'

'

'

'

'

6.00%

'

'

Maximum annual contributions by employer, amount

'

'

'

'

'

'

'

'

'

'

'

'

17,500

'

'

Matching contributions expensed for employee savings plan

'

'

'

'

'

'

'

'

'

'

'

'

$628,000

$512,000

$417,000

REVENUES_Details

REVENUES (Details) (USD $)

1 Months Ended

2 Months Ended

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Nov. 06, 2012

Dec. 31, 2012

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Revenues [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Sales of natural gas

'

'

'

'

'

'

'

'

'

$405,206

$325,421

$385,513

Sales of NGLs and condensate

'

'

'

'

'

'

'

'

'

169,523

124,139

106,487

Transportation, gathering and processing fees

'

'

'

'

'

'

'

'

'

59,392

46,113

30,102

Other

'

'

'

'

'

'

'

'

'

601

456

1,047

Total revenues

$55,613

$96,047

$175,140

$160,629

$154,703

$144,250

$118,150

$105,701

$120,618

$634,722

$496,129

$523,149

CONCENTRATION_OF_CREDIT_RISK_A2

CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Consolidated revenue concentration	'	'	'
Allowance for uncollectable accounts receivable	0	0	'
Formosa | Customer concentration | Consolidated revenue	'	'	'
Consolidated revenue concentration	'	'	'
Concentration risk percentage	'	24.30%	20.80%
Sherwin | Customer concentration | Consolidated revenue	'	'	'
Consolidated revenue concentration	'	'	'
Concentration risk percentage	11.70%	11.00%	15.50%
Top ten customers | Customer concentration | Consolidated revenue	'	'	'
Consolidated revenue concentration	'	'	'
Concentration risk percentage	59.70%	65.50%	73.10%
Number of top customers	10	10	10

SUBSEQUENT_EVENTS_Details

SUBSEQUENT EVENTS (Details) (USD $)

12 Months Ended

3 Months Ended

12 Months Ended

1 Months Ended

0 Months Ended

3 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Feb. 28, 2014

Apr. 12, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Cash [Member]

Cash [Member]

Cash [Member]

Cash [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Common units [Member]

General Partner [Member]

Cash [Member]

Cash [Member]

In Kind Distribution [Member]

Subsequent events

'

'

'

'

'

'

'

'

'

'

'

'

Minimum quarterly distribution (in dollars per unit)

'

'

'

$0.40

$0.40

$0.24

$0.40

'

'

$0.40

$0.40

'

Ownership interest held by limited partners (as a percent)

'

'

'

'

'

'

'

'

2.00%

'

'

'

Incentive Distribution, Distribution Per Unit

'

'

'

'

'

'

'

'

'

'

'

$0.40

Units authorized for public offering

'

'

'

'

'

'

'

9,200,000

'

'

'

'

Proceeds from issuance under public offering

'

$187,764,000

'

'

'

'

'

$148,800,000

'

'

'

'

Estimated cost of public offering

'

'

'

'

'

'

'

$400,000

'

'

'

'

SUPPLEMENTAL_CASH_FLOW_INFORMA2

SUPPLEMENTAL CASH FLOW INFORMATION (Details) (USD $)	3 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Supplemental Cash Flow Elements [Abstract]	'	'	'	'
Cash paid for interest, net of amounts capitalized	'	$13,043	$10,552	$7,994
Cash paid for taxes, net of refunds received	'	95	315	272
Supplemental schedule of non-cash investing and financing activities:	'	'	'	'
Accounts payable related to capital expenditures	'	4,946	40,707	10,862
Change in value recognized in other comprehensive income	'	148	745	0
Capital lease obligation	0	1,396	0	0
Accrued distribution equivalent rights (DERs) on the LTIP units	'	279	0	0
Other	'	$704	$0	$0

SUPPLEMENTAL_SELECTED_QUARTERL2

SUPPLEMENTAL SELECTED QUARTERLY FINANCIAL INFORMATION (UNAUDITED) SUPPLEMENTAL SELECTED QUARTERLY FINANCIAL INFORMATION (UNAUDITED) (Details) (USD $)

1 Months Ended

2 Months Ended

3 Months Ended

10 Months Ended

12 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Nov. 06, 2012

Dec. 31, 2012

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Nov. 06, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenues

$55,613

$96,047

$175,140

$160,629

$154,703

$144,250

$118,150

$105,701

$120,618

'

$634,722

$496,129

$523,149

Gross operating margin

6,741

9,707

28,174

25,213

21,296

18,863

15,078

18,698

21,416

'

93,546

71,640

'

Income (loss) from operations

-1,589

-3,998

4,485

-357

-2,831

-4,317

-2,686

3,442

8,120

'

-3,020

3,289

15,866

Net (loss) income

-4,394

-4,228

673

-4,069

-6,192

-6,382

-4,041

1,939

6,236

-260

-15,970

-4,488

7,539

Distribution to partners and LTIP unitholders

'

5,982

13,755

9,987

9,986

9,973

'

'

'

'

-35,992

0

0

Distribution paid in cash

'

'

'

'

'

'

'

'

'

'

43,701

5,982

'

Basic net (loss) income per common unit (in dollars per share)

'

'

$10

$190

($650)

($260)

'

'

'

'

'

'

'

Diluted net (loss) income per common unit (in dollars per share)

'

'

$10

($140)

($650)

($260)

'

'

'

'

'

'

'

Basic and diluted net loss per subordinated unit (in dollars per share)

'

($0.17)

'

'

'

'

'

'

'

'

($0.71)

($19.12)

($6.79)

Subordinated Units [Member]

'

'

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Basic and diluted net loss per subordinated unit (in dollars per share)

'

'

$10

($190)

($270)

($260)

'

'

'

'

'

'

'

General Partner [Member]

'

'

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Net (loss) income

'

-85

14

-81

-124

-128

'

'

'

'

-319

-85

'

Basic and diluted net loss per subordinated unit (in dollars per share)

'

($0.17)

'

'

'

'

'

'

'

'

'

($0.17)

'

Limited Partners [Member]

'

'

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Net (loss) income

'

($4,143)

$244

($17)

($11,294)

($6,254)

'

'

'

'

($17,321)

($4,143)

'

Basic and diluted net loss per subordinated unit (in dollars per share)

'

($0.17)

'

'

'

'

'

'

'

'

'

($0.17)

'